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Home My WebLink About205-078New Plugback Esets 7/31/2024 Well Name API Number PTD Number ESet Number Date CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 Mitre 1 PB1 50-103-20409-70-00 202-026 T39330 7-23-2002 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 S-04L1 PB1 50-029-23148-70-00 203-053 T39335 7-14-2005 S-04L1 PB2 50-029-23148-71-00 203-053 T39336 7-14-2005 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11-6-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 W-34A PB1 50-029-21867-70-00 203-058 T39341 2-6-2004 SP30-W01 PB1 50-629-23476-70-00 212-142 T39342 11-14-2012 V-207L4 PB1 50-029-23390-71-00 208-070 T39343 9-11-2008 W-215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 • Image Projeet Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~C Q`j - Q ~ ~ Weil History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria Scanning Preparation BY: Maria Production Scanning „~ Illllllllllillllil ~P x 30 = ~ + ~ d =TOTAL PAGES Date:" I ~ 9' /~ I, (Count does not i S~ude cover sheet) Stage 1 Page Count from Scanned File: ----E-- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: ~' / ~(~ O ~ /s/ ((( /l J Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II~I11 III II 11 III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III ~I~III III (I'I ICI ~,.os,~a iuuiimuiiiuu DIGITAL DATA Diskettes, No. ^ Other, No/Type: Date: Date: ae,~a~~eaaea uiimiieiiuiiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Lags of various kinds: ^ Other:: P 10/6/2005 Well History File Cover Page.doc aa~=o~-~ j ~ ~~~ Company ConocoPhillips, Alaska, Inc. ,, Well Name 1D-42L1PB1 ;~„~~~~;~ ;j~.~.~ ~~ ~ ~~D~ Date 1219/2009 BAILER Hu~HE~ INTEQ ~~ • Page 1 of 4 __ _ __, ~~ ~~~~ Company ConocoPhillips, Alaska, Inc. ~ ~ ~ ~ ;' ' Well Name 1D-42L1 n c ~ ~Ca~~ ` ~• ~-z~s~ Date 12/8/2009 ~~ BAKER HuGNE~ Il`TTEQ • ~~ ~J Page 1 of 4 1~ DATA SUBMITTAL COM LIANCE REPORT 7/19/2007 Permit to Drill 2050780 Well Name%No. KUPARUK RIV UNIT 1D-42L1 Operator CONOCOPHILLIPS ALASKA INC MD 10918 TVD 6334 Completion Date 7/16/2005 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD / GR Well Log Information: Log/ Electr Data Digital Dataset API No. 50-029-22979-60-00 UIC N Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / i e mearrrmt rvumper Name acme meaia No Start Stop CH Received Comments ED D Asc Directional Survey 9722 10918 8/9/2005 t Directional Survey 9722 10918 8/9/2005 ~ Ep / / D Asc Directional Survey 8400 10300 8/9/2005 PB 1 !' R pt Directional Survey 8400 10300 8/9/2005 PB 1 a "~D Li C s 14184 Gamma Ray 8407 10918 Open 10/19/2006 LIS Veri w/Graphics 0 14184 Gamma Ray 2 Blu 8415 10918 Open 10/19/2006 TVD GR 14-Jul-2005 og 14184 Gamma Ray 25 Blu 8415 10918 Open 10/19/2006 MD GR 14-Jul-2005 ~ DEB C Lis 14257 Gamma Ray '~~~ ~k~ 8407 10918 Open 11/29/2006 LIS Veri, GR, ROP w/Graphics C Lis 14260 Gamma Ray K~~~~,~„ 8407 10300 Open 11/29/2006 P61 ROP, GR w/Graphics Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? N Chips Received? Y7'1~~ Formation Tops 6/ N Analysis ~T`Mt' Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 7/19/2007 Permit to Drill 2050780 Well Name/No. KUPARUK RIV UNIT 1D-42L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22979-50-00 MD 10918 TVD 6334 Completion Date 7/16/2005 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: _ ~ Date: _~o ~~~ Transmittal Form • BAKER -- - --- - ,r~ w«.. NUGNES Anchorage GEOScience Center Contains the following: RE'V~SED 1 LDWG Compact Disc (Includes Graphic Image files) ~~~ 1 LDWG lister summary LAC Job#: 932692 INTEQ To: AOGCC 333 West 7t'` Ave, Suite 100 Anchorage, Alaska 99501 Attention: Helen Warman Reference: 1D-42L1 Sent By: Deepa Joglekar Bate; :1Vo3.l~7; 290 ~"` ,~ ~_. Received By: ~_ Date: _ PLEASE ACKNOWLEDGE RECEIPT BY SIGNII~~ ~'I'URNING OR FAXING YOUR COPY ' FAX: (907) 267-6623 Baker Hughes INTEQ ' 7260 Homer Drive ,~ - ~ ~ ~ at ~ 2', ~ J ~ Ancho 9g 18 asks. Direct: (907) 267-6612 PAX: (907) 267-6623 ~I ~:.! ~~ =- ; ` - - -~- - ~'- ~~. ~- - k ~- ~- ~.. ~ r Transmittal Form '~® BAKER HuCHES INTEQ Anchorage GEOScience Center To: AOGCC j 333 West 7th Ave, Suite 100 ~ Anchorage, Alaska ~°~~ 99501 Attention: Helen Warman ' °-°~ Reference: 1D-42L1PB1 ~ "°'p ;Contains the following: '~ R~`~IIS~D ~ 1 LDWG Compact Disc ?~ (Includes Graphic Image files) ~; i 1 LDWG lister summary tE i ~~ ', ~~ ~~ E if i~ I i f~ LAC Job#: 932692 Sent By: Deepa Jo lekar Date: V~ , 2~n6 °-~ ,~ Received By: Date ~d-~ ~ ~~ a ~~_° PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 _ Baker Hughes INTEQ ~~ ' ~ ~ ~ 7260 Homer Drive Anchorage, Alaska ~~(~~~ 9918 Direct: (907) 267-6612 FAX: (907) 267-6623 • Transmittal Form INTEQ • BAKER - -- n HUGHES -= = Anchorage GEOScience Center ~ ~,. i ~ 1: 1~I To: AOGCC ~ 333 West 7`h Ave, Suite 100 Anchorage, Alaska ! °°~~ 99501 Attention: Helen Warman III °~'- ''~ Reference: 1D-42L1 j °" " i Contains the following: 1 LDWG Compact Disc ~ (Includes Graphic Image files) 1 LDWG lister summary I blueline - GR 1Vlea;ured Depth Log 1 blueline - GR TVD Log j LAC Job#: 932692 `:.I Sent By• Deepa Jo~lekar Date: Oct.16, 2006 Received By: ~ ~~~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~. Baker Hughes INTEQ 7260 Homer Drive _ ~~~~"~~~ Anchorage, Alaska _ : _ 99518 l ! '~ ~ Direct: (907} 267-6612 FAX: (907) 267-6623 STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COM ~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~~~ AUG ~ , 2005 ~k~ D3E ~ ~~~ C" .,._ F ~,~rit~~~s~la~i 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned 20AAC 25.105 ^ GINJ ^ WINJ ^ WDSPL No. of Completions ^ Suspended ^ WAG 20AAC 25.110 One Other 1b. Well Class: ~O~~u~ ~~~ ® Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 7/16/2005 12. Permit to Drill Number 2f15-078 3. Address: c% P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/5/2005 13. API Number 50- 029-22979-60-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 7/14/2005 14. Well Name and Number: 1 D-42L1 567 FNL, 421 FEL, SEC. 23, T11 N, R10E, UM Top of Productive Horizon: 23' FNL, 1990' FEL, SEC. 26, Ti 1 N, R10E, UM g, KB Elevation (ft): 106' 15. Field /Pool(s): Kuparuk River Field /Kuparuk River Pool Total Depth: 1147' FNL, 38' FWL, SEC. 25, T11N, R10E, UM 9. Plug Back Depth (MD+TVD) 10918 + 6334 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 y- 595909 9 ASP4 Zone- 10. Total Depth (MD+TVD) 10918 + 6334 Ft 16. Property Designation: ADL 025661 _ _ _ __ _ TPI: x- 559144 _ y- 5954352 Zone- ASP4 Total Depth: x- 561182 Y- 5953243 Zone- ASP4 11 • Depth where SSSV set (Nipple) 512' MD 17. Land Use Permit: - --- ---- ~---------- - - ----~------ 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1627' (Approx.) 21. Logs Run: MWD / GR 2. ASING, LINER AND EMENTING RECORD CASING ETTING DEPTH MD ETTING EPTH TVD f{OLE MOUNT $IZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTING RECORD PULLED. 20" 91.5# H-40 Surface 115' Surface 115' 30" 50 sx Arcticset I 9-5/8" 40# L-80 Surface 5312' Surface 4225' 12-1/4" 600 sx AS III Lite, 350 sx LiteCrete 7" 26# J-55 Surface 8188' Surface 6089' 8-1/2" 170 sx Class 'G' 3-1/2" 9.3# L-80 8001' 8415' 5967' 6236' 6-1/8" 172 sx Class'G' 2-3/8" 4.6# L-80 8400' 10822' 6226' 6325' 3" Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" Slotted Section 3-1/2", 9.3#, L-80 8054' 8008' MD TVD MD TVD 8411' - 8475' 6233' - 6267 8665' - 9934' 6272' - 6269' 25. ACID, FRACTURE, CEMENT SQUEEZE, .ETC. 10280' - 10788' 6313' - 6324' DEPTH INTERVAL MD AMOUNT $i KIND OF MATERIAL USED 8415' Set Weatherford Flow-Thru Whipstock 2500' Freeze Protected with 25 Bbls of Diesel 26. PRODUCTION TEST Date First Production: July 21, 2005 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 7/25/2005 Hours Tested 11 PRODUCTION FOR TEST PERIOD OIL-BBL 957 GAS-MCF 1,689 WATER-BBL 1,561 CHOKE SIZE 95 GAS-OIL RATIO 1,766 Flow Tubing Press. 44 Casing Pressure 1,380 CALCULATED 24-HOUR RATE OIL-BBL 2,087 GAS-MCF 3,686 WATER-BBL 3,406 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~ ~ , ~~ ~ ~ ;~a ~~ %, o~ ~~~o~a-~ SyIS ,~~ 235 ~~/,~ Non .~ 1'~ s ®~~ A~~ ~ ~ 2~~5 I~ OR~G~NAL. ~~~ . Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKER 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Kuparuk C (From Original Drill) 8413' 6234' None Kuparuk B 9958' 6272' Kuparuk C 10252' 6310' Kuparuk B 108$8 6330' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Q Signed Terrie Hubble / Title Technical Assistant Date ~ v ~' `~ (~ 5 1 D-42L1 205-078 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Aras Worthington, 265-6802 Permit No. / A royal No. INSTRUCTIONS GeNEaA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. frets 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Well: 1 D-42L1 Accept: 07/02/05 Field: Kuparuk River Field Spud: 07/05/05 API: 50-029-22979-60-00 Release: 07/16/05 Permit: 205-078 Ria: Nordic #2 PRE-RIG WORK 05/01 /05 DRIFTED WITH 2.74" X 10' DUMMY WHIPSTOCKTO 8451' WLM. 06/09/05 RUN 2.48" CENT SBHP GAUGES TO 1ST STOP AT 8445' RKB 30 MIN , 2ND STOP AT 8290' RKB 15 MIN. SBHP OF 2398 PSI AT 8445' RKB (152 DEG F). 06/16/05 SET CA-2 PLUG AT 7972' RKB, PULLED GLV'S FROM 2653', 4840, & 6236' RKB. SET DV'S IN TOP TWO STATIONS. IN-PROGRESS. 06/17/05 PUMPED DIESEL & SEAWATER TO LOAD WELL DOWN TO STA #3 AT 6236' RKB. SET DV IN STA.# 3, MITT TO 3000PS1, PASSED. MITIA TO 2500PS1, PASSED. PULLED CA-2 PLUG. FROM 7972' RKB. 06/27/05 PLUG PERFORATIONS WITH A 27.5 BBLS CACO3 PILL. HESITATION SQUEEZED IN-PLACE AND TESTED, ql<. BP EXPLORATION Operations Summary Report Page 1 of 11 Legal Well Name: 1 D-42 Common Well Name: 1 D-42 Spud Date: 11/8/2000 Event Name: REENTER+COMPLETE Start: 7/1/2005 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code - _ ~ _ I NPT I Phase 7/2/2005 ~ 16:30 - 20:00 ~ 3.50 ~ MOB P ~ ~ PRE 20:00 - 00:00 I 4.00 I BOPSUR P I I PRE 7/3/2005 100:00 - 04:00 I 4.001 BOPSUR P I I PRE 04:00 - 08:45 I 4.751 BOPSURN I RREP (PRE 08:45 - 10:00 1.25 KILL P 10:00 - 12:30 2.50 KILL P 12:30 - 13:00 0.50 KILL P 13:00 - 14:45 14:45 - 15:15 15:15 - 16:30 1.751 KILL I P 0.50 KILL P 1.25 KILL P 16:30 - 18:45 2.25 KILL P 18:45 - 19:00 0.25 KILL P 19:00 - 19:45 0.75 STWHIP P 19:45 - 21:35 1.83 STWHIP P 21:35 - 22:40 1.08 STWHIP P 22:40 - 22:55 I 0.251 STWHIPI P 22:55-00:00 ~ 1.08~STWHIP~P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT W EX{T Description of Operations Move off of 1 D-37. Pick up mats and herculite and reset on 1 D-42. Move rig over 1 D-42 and set down Accept rig for operations at 2000 hrs 712/2005 ND tree cap. NU BOPE. Fill stack w/ water and body test to 3500 psi Reset camps, cuttings box, dumpsters, etc. DTH add hardline to existing line to tiger tank and PT Initial BOPE test (3500/350). Witnessed by AOGCC. Annular failed to test Replace annular element. MU lubricator to floor. Test annular to 400 psi and 3000 psi for 10 minutes each. No bleed off. Rig up floor for CTD operations. Hold PJSM. Pressure deploy Integ BHA with straight motor and D331 DSM mill for clean out. SITP: 295 psi. Surface test mwd. Strip over coil. Get on well. Hold PJSM to discuss well kill with replacement crew. Discuss wind. direction, safe area, assignments & procedures. Discuss hazards and need to shut down ops if any problems or concerns noted. Notify DS operator. RIH. Hold 350 psi WHP. Returns appear to be 100% diesel as per mm out density of 6.8 - 6.9 ppg. Up wt C~3 8200': 22.4k#. Dn wt: 9.5k# Log gr tie in from 8290'. Subtract 10' correction. RIH at 25 fpm. Circ at 4050 psi C~ 1.55 in/1.68 out. WHP: 355 psi. BHP: 4150 psi. ECD: 13.5 ppg. IA/OA/PVT: 367/454/368 bbls. Gradually reduce WHP to zero as mud comes up backside. Appear to be in CaCO pill at +/- 8310'. Take 25' bites and POOH 100' to chase it. Wash to 8400'. Circulate until 8.8 ppg mud back to surface. Wash to 8425'. 2400 psi @ 1.03 in/1.01 out. Chase up hole 100'. Wash to 8450'. 2470 psi C 1.02 in/1.07 out. Chase up hole 100'. Perfs now exposed. Begin losing 0.25 bpm. IA up to 620 psi. Bleed to 100 psi. Circulate out of hole at 80%. Safety mtg re: BHA change Flowcheck, static LD cleanout assy. MU WIS WS assy RIH w/ BHA #2 circ thru EDC 0.2/950 w/full returns Log tie-in w/ GR down from 8270-8351'. Corr -10' to SS DGR 10/22/00 Log tie-in w/ CCL down from 8341-8445' w/ 8.5k do wt. See collars at 8314', 8346' and 8378' within 2' of SWS Perf Record of 2/23/2001. Next one would be at 8408' PUH 2O.6k to 8421' and park Close EDC. Pressure up to 3607 psi and tool stroked. Stack 3k from 8424' to verify set. PUH 21.6k and CT press bled off. Park. Open EDC Set WS at 15L w/ top at 8415', RA at 8420.7' (preliminary depths) POOH for milling assy filling thru EDC 1.0!1700 w/ 10.16 ECD Printed: 7/18/2005 11:19:52 AM BP EXPLORATION Page 2 of 11 Operations Summary Report Legal Well Name: 1 D-42 Common Well Name: 1 D-42 Spud Date: 11/8/2000 Event Name: REENTER+COMPLETE Start: 7/1/2005 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours I Task Code NPT ' Phase 7/4/2005 00:00 - 00:15 0.25 STWHIP P WEXIT 00:15 - 01:30 1.25 STWHIP P WEXIT 01:30 - 03:20 i 1.831 STWHIPI P J J WEXIT 03:20 - 06:00 2.67 STWHIP P WEXIT 06:00 - 10:30 4.50 STWHIP P WEXIT 10:30- 11:30 1.001 STWHIPIP (WEXIT 11:30-13:15 I 1.751 STWHIPIP I (WEXIT 13:15 - 13:45 I 0.501 STWHIPIP I I WEXIT 13:45 - 14:45 I 1.001 DRILL I P I I PROD1 14:45 - 15:15 I 0.501 DRILL I P I I PROD1 15:15 - 15:45 0.50 DRILL P PROD1 15:45 - 16:30 0.75 DRILL P PROD1 16:30 - 18:00 1.50 DRILL P PRODi 18:00 - 18:50 0.83 DRILL P PROD1 18:50 - 20:00 1.17 DRILL P PROD1 20:00 - 22:30 2.501 DRILL P PROD1 22:30 - 23:30 1.00 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 7/5/2005 00:00 - 01:00 1.00 DRILL P PROD1 01:00 - 07:30 6.50 DRILL P PROD1 07:30 - 10:00 2.50 DRILL P PROD1 10:00 - 14:30 4.50 DRILL P PROD1 Description of Operations Fin POOH w/ WS setting tool LD setting assy and load out. LD MW D assy and reconfigure for milling. MU BHA w/ BTT motor, HCC 2.74" window mill and SR RIH w/ BHA #3 circ 0.25/1100. Tag WS at 8424' CTD. Start motor 1.5/1.2/3560 and RIH to first MW at 8423.4'. Corr to 8415' and flag PVT 290 Mill window from 8415' 1.51/1.45/3600 w/ 11.44 ECD Mill ahead at 8418'. 3400 psi fs C~3 1.5 in/1.5 out. 100-200 DPSI. DHWOB:1.5k#. WHP/BHP/ECD: 37/3610/11.4 ppg. IA/OA/PVT: 693/477/275 bbls. Continue to time mill at 0.1' per six minutes. Drill formation to 8430' Ream and back ream window, three up and down passes at 1 fpm. Dry drift window. Window smooth. Catch btms up sample: looks like formation sand. Circulate out of hole. Hold PJSM in ops cab near surface. Tag up. Flow check well. Get off well. Unstab from BHA. Blow down and LD BHA. Mill and SR in gauge (2.74") Prep to RU coil straightener and goose neck. Unstab coil from injector. Cut & prep coil to unstab. Hold PJSM to discuss unstabing & securing coil on pipe shed roof. Crane on location. Hold PJSM to discuss lifting gooseneck to rig floor. Make pick. Release crane. Unstab coil and secure on roof and at levelwind in reel house.. Hold pre spud mtg with entire crew. Aras Worhtington presented material. Remove goose neck from injector. Crew change, then Pre-spud mtg w/ nite crew w/ Aras Install CT straightener, then install gooseneck and cutter. Pull CT and stab Surface test using different hydraulic settings and moving adjuster while cut off CT (and wire) in +/-10' lengths. Cut off 357'. Determined that memory can be halved, but not completely removed and will provide no benefit to our operation at this time. Sean McLaughlin will provide more details Remove cutter. Clear floor of CT and wire. Clean up floor area. Stab back onto lub Displace mud in CT w/ FW prior to blowdown w/ N2 Blow down CT w/ N2 and bleed off Unstab CT and pull back to reel and secure. Load out the used 2" E-CT and bring in the new 2" E-CT. RU hardline in reelhouse. Concurrently RD gooseneck and pipe straightner and install old gooseneck Install hardline and a-line connections inside reel. Test same. Stab coil. Install connector. Fill coil with fresh water. Pump e-line slack. Install a-coil head. Pressure and pull test same. Test a-line connections. All good. Printed: 7/18/2005 11:19:52 AM BP EXPLORATION Page 3 of 11 Operations Summary Report Legal Well Name: 1 D-42 Common Well Name: 1 D-42 Spud Date: 11/8/2000 Event Name: REENTER+COMPLETE Start: 7/1/2005 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: D t F T H T k C d NP O a e rom - o ours as o e T Phase t Description of perations - 7/5/2005 - 14:30 - 15:15 0.75 DRILL P _ _. PROD1 _ __ MU drilling build assembly (BHA #4, 2.8 deg mtr w/ HCC bi-center bit) while displace water from coil. Stab coil. Test mwd. Get on well. 15:15 - 17:45 2.50 DRILL P PRODi Run in hole circulating at minimum rate. 17:45 - 22:45 5.00 DRILL P PROD1 Drilling from 8430' to 8490'. Gamma mis-reading. Confer w/ Geologist and DD. Decision made to continue drilling ahead without GR. 22:45 - 23:15 0.50 DRILL P PROD1 Short Trip w/ CT and BHA to 7860'. Run back to bot and continue drilling. 23:15 - 00:00 0.75 DRILL PROD1 Drill from 8490' to 8510'. 30-45 ROP, 3645 BHP. 7/6/2005 00:00 - 02:30 2.50 DRILL P PRODi Drilling from 8510 to 8578. Finish build. POOH. 02:30 - 04:00 1.50 DRILL P PROD1 POOH w/ CT and BHA. 04:00 - 04:15 0.25 DRILL P PROD1 Conduct safety meeting over undeployment procedure 04:15 - 06:00 1.75 DRILL P PRODi Undeploy and LD Build BHA. 06:00 - 07:45 1.75 DRILL P PROD1 Pressure deply lateral BHA. 07:45 - 09:20 1.58 DRILL P PROD1 TIH 09:20 - 10:25 1.08 DRILL P PRODi Log Gr marker -8' correction. RA tag at 8419' Corrected window depths: TOW 8415.6' BOW 8419.3' MAD pass to bottom. 10:25 - 15:00 ~ 4.581 DRILL ~ P ~ ~ PROD1 15:00 - 16:30 I 1.501 DRILL I P I I PROD1 16:30 - 17:00 0.50 DRILL P PRODi 17:00 - 23:00 6.00 DRILL P PRODi 23:00 - 00:00 I 1.001 DRILL I P I I PROD1 7/7/2005 00:00 - 03:00 3.001 DRILL P PRODi 03:00 - 03:30 0.50 DRILL P PROD1 03:30 -04:30 1.00 DRILL P PROD1 04:30 - 05:30 1.00 DRILL P PROD1 05:30 - 08:45 3.25 DRILL P PROD1 08:45 - 12:45 4.00 DRILL P PROD1 12:45 - 13:40 0.92 DRILL P PROD1 13:40 - 20:00 6.33 DRILL P PROD1 Directrionally drill ahead f/ 8578' 0= 1.51/ 1.51 8.86/8.87ppg FS= 3450psi ECD= 11.36ppg pit vol= 250bb1s. Slow going through B shale. Drilling ahead f/ 8667' 0= 1.55 / 1.56 8.8 in/out ECD 11.43ppg IA/OA 508/511 2-3k wob 20'/hr maintainoing 91.3 deg incl. Break into good drilling at 8700' 100+'/hr Wiper trip to window. Hole acting okay. Directionally drill aheadf/ 8725' to 9025'. 0= 1.55 FS= 3375psi ECD= 11.5 2-3k wob 100'/hr. @ 1900- slowed to 65'/hr. Perform wiper trip to 8200' while circulating. Corrected depth at RA marker of 1'. Continue Drilling from 9025'. Drill from 9025' to 9150' .Corrected depth w/ RA- 1'. 0=1.55, 3700 press, 50'/hr. C~J0200: ECD-11.5, LSRV-38K, Solids- 2%. Order out 425 bbls 8.8 ppg. Drilling Ahead to 9150'. 0=1.63, 3800 press, 22'/hr, ECD=11.7 Wiper trip to 8400'. Trip in to bot. and circulate at 1.58 bpm. Directionally drilling ahead f/ 9150'. Drilling on what appears to be Siderite stringer. 0= 1.57 FS= 3450 ECD 11.66ppg 2-300psi MW 3-4k wob 10'/hr pit vol= 247bb1s Drilling ahead f/ 9170' 0= 1.58 2-3k wob 50-60'/hr ECD= 11.74 Drifting back into Siderite at 9250'. Drilled to 9300' Swapped to new Flo-Pro mud system 4% Lube-tex 8ppb Kla-Guard 60k C~? 9250'. Initally higher pressures 0= 1.5 FS 3520 ECD= 11.9ppg Wiper trip to window. Up wt 22k dwn wt 9k. Hole in good shape. Directionally drill ahead f/ 9300'. 0=1.54 / 1.56 FS= 3500 ECD= 11.94 2-400psi MW 2k wob 50-60'/hr CT string wt 6k Printed: 7/18/2005 11:19:52 AM BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: 1 D-42 Common Well Name: 1 D-42 Spud Date: 11/8/2000 Event Name: REENTER+COMPLETE Start: 7/1/2005 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date i From - To Hours ~ Task Code NPT Phase ~ Description of Operations 7/7/2005 20:00 - 20:30 0.50 DRILL P PROD1 Drilling ahead from 9441'. 0=1.7, 4100 press, 12.05 ECD, 30'/hr 20:30 - 21:45 1.25 DRILL P PRODi Wiper trip to 8400'. 21:45 - 23:15 1.50 DRILL P PROD1 Drill ahead from 9451'. 0=1.72, 4100 press, 12.0 ECD, 25'/hr 23:15 - 23:30 0.25 DRILL P PROD1 Circulate BU to prepare for Trip. Hard to steer, Dropping ROP. 23:30 - 00:00 0.50 DRILL P PRODi POOH w/ CT and BHA (out of hole at 0145 hrs) ----------------------------------Ops at TIH w/ CT and BHA 7/8/2005 00:00 - 01:45 1.75 DRILL P PROD1 POOH w/ CT and BHA 01:45 - 02:30 0.75 DRILL P PROD1 Undeploy BHA- Change out Motor, Flapper Valve Sub, Bit 02:30 - 04:00 1.50 DRILL P PROD1 Deploy BHA- new .8 degree motor, bit, flapper valve sub 04:00 - 05:35 1.58 DRILL P PROD1 RIH w/ CT and BHA 05:35 - 05:50 0.25 DRILL P PROD1 Log tie-in -5' correction 05:50 - 06:25 0.58 DRILL P PROD1 RIH to bottom. Hole good. 06:25 - 11:55 5.50 DRILL P PROD1 Directionally drill ahead f/ 9475'. 0= 1.58 / 1.59 FS= 3500 ECD= 11.78 2-3k wob 20'/hr 11:55 - 13:15 1.33 DRILL P PROD1 Wiper trip to window. PU 20k SOW 7-10k hole good shape. No problems 13:15 - 16:45 3.50 DRILL P PROD1 Directionally drill ahead 0= 1.45 / 1.48 8.78/8.83 ECD= 11.82 (reduced flow rate to help build angle). FS= 3300 1-200psi MW 1-2k wob ROP varies 20-60'/hr 16:45 - 18:00 1.25 DRILL P PROD1 Wiper trip to window. PU wt 22k 18:00 - 22:30 4.50 DRILL P PRODi Drill ahead from 9800' to 9975'. 0=1.5, 4100 psi, 11.87 ECD, ROP varied. 22:30 - 00:00 1.50 DRILL P PRODi Wiper trip to 8000'. Tie in to RA Tag. 3' adjustment. ------Ops at 0530--------- Drilling ahead at 10115' with .3 bpm loss 7/9/2005 00:00 - 00:30 0.50 DRILL P PRODi Finished wiper trip from 8400'. 00:30 - 02:00 1.50 DRILL P PROD1 Drill ahead from 9975' to 10,011. 0= 1.45, 3600 press, 11.94 ECD, 3750 WOB, 10'/hr. 02:00 - 04:00 2.00 DRILL P PROD1 Drilling ahead from 10,011 to 10,087' . 0= 1.42, 3600 press, 11.95 ECD, 4500 WOB, 50'/hr 04:00 - 05:00 1.00 DRILL P PROD1 Drilling ahead from 10087 to 10115'. 0= 1.41, 3650 press, 12.02 ECD, 4500 WOB, 70'/hr 05:00 - 06:15 1.25 DRILL P PROD1 Losing fluid at .3 bpm. Healing as we drill ahead. 0=1.431/1.260, 3600 press, 11.84 ECD, 2790 WOB, 70'/hr 06:15 - 08:00 1.75 DRILL P PROD1 Wiper trip to window. Hole good. 08:00 - 11:25 3.42 DRILL P PROD1 Directionally drilling ahead f/ 10125' 0= 1.49 / 1.40 EDC= 12.01 FS= 3400 MW 2-300psi 2-3k wob ROP varies some hard streaks general drilling good @ 50-60'/hr. Mud loss rate avg 5-8bbls/hr. (New mud ordered this system has close to 1000' on it. New mud will have increase in lubetex to 4-1/2% and additional 1%of EMI 776) 11:25 - 16:00 4.58 DRILL P PRODi Lost 50% returns at 10196'. PU wt check 21.2k dwn 6.6k Drill ahead 0= 1.44 / .79 initial.. Fast drilling to 10213' then slowed to <10'/hr. Drilled ahead slowly to 10250' losses here have healed slighlty 0= 1.48 / 1.18 16:00 - 18:15 2.25 DRILL P PRODi Wiper trip to window. PU wt clean at 22k. Reconditoned 290 bbls 8.8ppg mud arrived from MI -offload to rig. Fill tank#4 with new mud for lubricant "sweeps". Printed: 7/18/2005 11:19:52 AM BP EXPLORATION Page 5 of 11 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: 1 ell Name: 1 e: Name: From - To , D-42 D-42 REENTE NORDIC NORDIC Hours R+COM CALIST 2 Task PLET A Code E NPT Start Rig Rig Phase Spud Date: 11/8/2000 : 7/1/2005 End: Release: Number: ~ Description of Operations 7/9/2005 18:15 - 19:00 0.75 DRILL P PROD1 Drill ahead from 10250' to 10260' . 0= 1.42 I/1.2 O, 3800 press, 11.9 ECD, 3750 WOB, 12'/hr. 19:00 - 19:15 0.25 DRILL P PRODi Circulate 10 bbl sweep with EMI 776 polymer. 19:15 - 21:00 1.75 DRILL P PROD1 Drill ahead from 10260' to 10282'. 0= 1.42/1.22, 3700 press, 11.95 ECD, 4500 WOB, 9.5'/hr. May have passed into fault and drilling through Kalubik shale. Call into town. 21:00 - 21:30 0.50 DRILL P PROD1 Circulate 10 bbl sweep with EMI 776 polymer. Conduct micro trip. 21:30 - 22:00 0.50 DRILL P PROD1 Drill ahead from 10282' to 10288' . 0= 1.45/1.31, 3750 press, 11.78 ECD, 4100 WOB, 11'/hr. 22:00 - 22:15 0.25 DRILL P PRODi Circulate 10 bbl sweep with EMI 776 polymer. Conduct micro trip. 22:15 - 23:00 0.75 DRILL P PROD1 Drill ahead from 10288' to 10300' . 0= 1.64/1.42, 4200 press, 12 ECD, 1500 WOB, 10'/hr. 23:00 - 23:45 0.75 DRILL P PROD1 Circulate 10 bbl sweep with EMI 776 polymer. Conduct micro trip. 23:45 - 00:00 0.25 DRILL P PRODi Cease drilling and TOH for sidetrack. 7/10/2005 00:00 - 02:30 2.50 DRILL P PROD1 POOH w/ CT and BHA to sidetrack 02:30 - 04:00 1.50 DRILL P PRODi ~ Undeploy CT BHA 04:00 - 05:30 1.50 STKOH C PROD1 Orient and Deploy CT Sidetrack BHA 05:30 - 07:00 1.50 STKOH C PROD1 TIH w/ CT and Sidetrack BHA 07:00 - 07:15 0.25 STKOH C PROD1 Log tie-in -7' correction 07:15 - 07:45 0.50 STKOH C PROD1 RIH min rate. No returns but folllowing pressure schedule. Hole good shape. RIH to 9759'. Pull up to 9735' while closing EDC. Bring pump rate to 1.50 07:45 - 09:50 2.08 STKOH C PROD1 Orient to 160-170R. Start OHST at 9735'. 0= 1.50 / 1.30 FS 3440 Ann 3700 ECD 11.64. Trough at .3'/min to 9750'. No MW seen. Repeat again from 9735' to 9750' 09:50 - 10:45 0.92 STKOH C PROD1 Drili ahead f/ 9750' 20-80psi MW. Drilled to 9775' Near bit survey showing OHST is successful (9761' 82.6deg) Hold table top Rig Evac an H2S dri I. 10:45 - 13:00 2.25 STKOH C PROD1 TOH PU wt 22k follow pressure schedule. 13:00 - 15:00 2.00 STKOH C PRODi Pressure undeploy 500psi on well. Change out bits. PU 0.8 deg motor. As required by AOGCC fuction tested all BOPE componets. Redeploy new BHA. Well still had 475psi. 15:00 - 17:00 2.00 STKOH C PROD1 RIH with BHA #7 following pressure schedule. (R-60 OHST bit returned to Deadhorse for another brass cap install) 17:00 - 17:10 0.17 STKOH C PROD1 Log tie-in -9' correction. 17:10 - 19:00 1.83 STKOH C PROD1 RIH to 9650'. Orient lowside RIH 19:00 - 22:45 3.75 STKOH C PROD1 Make final pass with bit to sidetrack- trouble locating starter hole in trough. Will not go. POOH. 22:45 - 00:00 1.25 STKOH C PROD1 POOH to change motor and bit 7/11/2005 00:00 - 01:00 1.00 STKOH C PROD1 POOH w/ CT and BHA 01:00 - 02:15 1.25 STKOH C PROD1 Undeploy BHA 02:15 - 04:00 1.75 STKOH C PROD1 Deploy BHA: same bit, new 1.7 motor 04:00 - 06:00 2.00 STKOH C PROD1 TIH w/ CT and BHA. Tie in correction at window: -11'. 06:00 - 10:50 4.83 STKOH C PROD1 At 9725' orient to low side RIH min rate. Enter new hole see motor work > O 1.50bpm. RIH to 9775' NB survey confirms new hole. Slowly back ream. 0=1.78 / 1.56 FS 3750 RIH to 9775. (only able to do so with min rate) reaming slowly back to 9775' at full pump rates. Repeat this procedure working Printed: 7/18/2005 11:19:52 AM BP EXPLORATION Page 6 of 11 Operations Summary Report Legal Well Name: 1 D-42 Common Well Name: 1 D-42 Spud Date: 11/8/2000 Event Name: REENTER+COMPLETE Start: 7/1/2005 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Hours ~ Task Code j NPT ~ Phase Date From - To _~ ~ 7/11/2005 106:00 - 10:50 ~ 4.831 STKOH ~ C ~ ~ PRODi 10:50 - 13:00 2.17 STKOH C 13:00 - 14:00 1.00 STKOH C 14:00 - 15:30 1.50 STKOH C 15:30 - 16:30 1.00 STKOH C 16:30 - 19:00 2.50 STKOH C 19:00 - 21:00 2.00 DRILL C 21:00 - 23:00 I 2.001 DRILL IC 23:00 - 00:00 1.00 DRILL C 7/12/2005 00:00 - 01:45 1.75 DRILL C 01:45 - 03:30 I 1.751 DRILL I C 03:30 - 09:45 I 6.251 DRILL I C 09:45-12:15 ~ 2.50~DRILL ~C 12:15 - 19:00 ~ 6.75 ~ DRILL ~ C 19:00 - 20:30 I 1.501 DRILL I C 20:30 - 20:40 0.171 DRILL C 20:40 - 21:30 0.831 DRILL C 21:30 - 22:15 0.751 DRILL ~ X 22:15 - 23:45 I 1.501 DRILL I C PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PRODi DPRB PROD1 PROD1 Description of Operations back to 9720' multiple times. Changing TF from 140E to 140R and highside. Finally able to RIH with full pump and enter OHST with 165R TF TOH following pressure schedule trap 700psi on well. Pressure undeploy BHA 520psi on well. Change motor setting to 1.1 deg. Cut and slip 50' of drilling line and 60' of slick line. Installed new injector pack-off elements. P/U and deploy BHA #10 550psi on well. TIH follow pressure schedule. Drill ahead from 9750' to 9845' .Taking time to keep hole clean. 0=1.6/1.45, 3650 press, 11.5 ECD, 1700 WOB, 17'/hr. Drill ahead from 9845' to 9940'. 0= 1.6/1.45, 3800 press, 11.5 ECD, 2700 WOB, 36'lhr. Perform wiper trip- POOH to window (8400') Wiper trip to window (8400'). Time Reamed on way out of sidetrack. Slowed pumps on re-entry. No problem re-entering sidetrack. Drill ahead from 9940' to 9975' . 0=1.58/1.42, 3650 press, 11.5 ECD, 3200 WOB, 9'/hr. Drill ahead from 9975' to 10100'. 0= 1.5/1.4, 3650 press, 11.64 ECD, 1200 WOB Wiper trip to window. Slow down f/ 9775' to 9720'. Okay to window. RIH charge pumps shutdown. Unable to pump. POH maintain 500psi on choke. Pull up hole. Electrical problem fixed and leaking cap on Pump #2 discharged fixed. RIH. Orient to lowside went through OHST wo problems at full pump rate. Continue RIH with as drilled TF's. Small setdown at 10055'. PU and wiper through area. RIH setdown again at 10058' PU. RIH at reduced pump rate .45 to 10090'. PU cleanup area. RIH to TD. Directionally drill ahead f/ 10100'. 0= 1.65 / 1.46 FS= 3750psi 2-300psi MW WOB= 1-2k 50-60'/hr slowed at 10155' to < 10'!hr 3-4k wob (Siderite) Broke through siderite at 10205' back to drill 20-30'/hr Wiper trip to window. Clean PU off bottom at 21 klbs. 1.57/1.34/3670 psi. Pit vol = 404 bbls. IAP=320 psi, OAP=381 psi. Slight motor work in shale at 10064'-10024'. Slowed down and reamed bad spot 1 time. Not real bad. Pull ti window. SD pumps, open EDC Pump at full rate while PUH in tubing. Log tie in pass over RA tag in whipstock. Make +4' depth correction. Continue back in hole on wiper trip. Smooth thru the open hole sidetrack at 9750'. Set down at 9997'. PU and ran down thru 9997' ok to 10074'. Backreamed up at 8 fpm. Got a little motor work and overpull at 10045'. B shale talking to us a little bit. Call MI yard in Deadhorse to send out additional Kla-Gard. System currently at 8 Ib/bbl. Call for enough to raise system to 12 Ib/bbl. Continue in hole. Set down at 10105'. PUand work thru it to 10140'. Backream up at 8 fpm. R1H ok, set down at 10199'. Work down thru it slowly. Resume drilling. Free spin is 3500 psi at 1.5 bpm. Up weight is 22 klbs. Drilling at 1.51/1.34/3670 psi. Pit vo1=408 bbls. Printed: 7/18/2005 11:19:52 AM BP EXPLORATION Page 7 of 11 Operations Summary Report Legal Well Name: 1 D-42 Common Well Name: 1 D-42 Spud Date: 11/8/2000 Event Name: REENTER+COMPLETE Start: 7/1/2005 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: - _ ~ Task Code ' .Phase Description of Operations -Date _ _ From - To ,i Hours I NPT II - - -- __ _ _ _ -_ 7/12/2005 22:15 - 23:45 1 50 DRILL C ~ ~ PROD1 ~ ECD=11.76 ppg, BHP=3777 psi. ROP=40 fph. 23:45 - 00:00 0.251 DRILL C PROD1 7/13/2005 00:00 - 02:50 2.831 DRILL P ( PROD1 02:50 - 03:15 I 0.421 DRILL I P I I PROD1 03:15 - 03:40 0.42 DRILL N DPRB PROD1 03:40 - 05:30 1.83 DRILL P PROD1 05:30 - 07:00 I 1.501 DRILL I P 07:00 - 10:45 I 3.751 DRILL I P 10:45 - 12:15 I 1.501 DRILL I P 12:15 - 16:20 I 4.081 DRILL I P 16;20 - 15:50 23.50 ~ DRILL P 15:50 - 16:50 1.00 DRILL P 16:50 - 21:10 4.33 DRILL P 21:10 - 22:40 I 1.501 DRILL I P 22:40 - 22:50 0.17 DRILL P 22:50 - 00:00 1.17 DRILL P PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PRODi PROD1 Geo picks fault at 10252'. Losses increased at 10295' to 1.5/1.0/3730 psi. Slowly came back. Continue drilling ahead as per plan. 1.55/1.25/3670 psi. Pit volume = 364 bbls. Began adding Kla-gard to system. Bringing concentration up to i2 #/bbl. Wiper trip to window. PU off bottom at 24 klbs. Motor work, and packing off at 10064'. Slow down and backream thru section at 8 fpm. Ream from 10124'-9997'. Cleaned up finally. Continue wiper trip to window with no problems. Run back in hole. No problems at OH sidetrack. Made it back thru problem area at 9995'-10074' with only 1 small weight bobble. This area appears to be improved from last 2 wiper trips. Resume drilling. f/ 10388' 1.52/1.22/3790 psi. Pit vol = 302 bbls. IAP=300 psi, OAP=330 psi. ROP= variable and ratty. Geo reports siderite in cuttings. ECD=11.66 ppg. BHP = 3754 psi. Drill to 10422 Continue drilling ahead f/ 10422' 1.55 / 1.25 FS 3750psi 1-200psi MW drilling on siderite stringer 3k wob -3k coil wt. In and out of siderite stringers every 3'-5' Finally out around 10455' 1.5k wob (-3.6k coil wt) with 60'/hr drilling rate. Good drilling to 10480', .intermittent to 10500'. Weight transfer doesn't appear to be a problem. Loading 2-3/8" liner in pipe shed. Wiper trip. Clean pick-up off bottom 22-23k. 1.56bpm 100psi MW at 10386', 10067', 10032'. clean to 9500' OHST good. RIH with "as drilled" TF's good to 10090 then 100psi MW down to 10130' good to 10420' pu change TF to 90L RIH good to 10500'. Directionally drill ahead f/ 10500' 0= 1.52 / 1.12 FS= 3650 stall at 10575' then lost another .3bpm returns 0=1.56 / 0.8 200psi MW slowly regaining good drilling 2k wob 100'/hr (-3.7k coil wt) to 10620' the struggle with siderite stringers to 10650' w/ 2k wob and -5k coil wt. 0= 1.56 / 1.0 Wiper trip to window. 0= 1.56 MW and 2k overpulls at 10022'-10010' Wiper trip back in the hole. No significant motor work while RIH. 6 shale appears to be in better shape than last night. Thank you Kla-Gard. Resume drilling. Free spin = 3580 psi at 1.51 bbl/min. Drilling at 1.51/1.13/3670 psi. On a hard siderite stringer. ROP=15 fph. String wt = -6500 lbs. WOB=2500 lbs. Getting difficult to get weight on bit. Nearing lockup. Pit volume = 325 bbls. IAP=256 psi, OAP=300 psi. ECD=11.57 ppg. BHP=3730 psi, WOB has been trending down. We are at -7500 Ibs string weight with only 250 Ibs on downhole bit weight sensor. Do a wiper trip to clean hole to see if that will allow us to resume drilling. PU at 21 klbs clean. 1 small blip of motor work at 10043'. Clean Log tie in pass over RA tag. Make +7' correction. Run back in hole to complete wiper trip. Printed: 7/18/2005 11:19:52 AM BP EXPLORATION Operations Summary Report. Legal Well Name: 1 D-42 Common Well Name: 1 D-42 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ;From - To ~ Hours ' Task Code NPT 7/14/2005 ~ 00:00 - 03:15 ~ 3.25 ~ DRILL P 03:15 - 05:00 I 1.751 DRILL I P 05:00 - 06:00 I 1.001 DRILL I P 06:00 - 09:00 I 3.001 DRILL I P 09:00 - 11:45 2.75 DRILL P 11:45 - 15:10 3.42 DRILL P 15:10 - 18:10 I 3.001 DRILL I P 18:10 - 18:30 0.33 DRILL P 18:30 - 18:45 0.25 DRILL P 18:45 - 19:15 0.50 DRILL P 19:15 - 19:50 0.58 CASE P 19:50 - 20:15 0.42 CASE P 20:15 - 20:30 0.251 CASE I P Page 8 of 11 Spud Date: 11 /8/2000 Start: 7/1/2005 End: Rig Release: Rig Number: Phase Description of Operations PROD1 Resume drilling. Free spin = 3550 psi at 1.45 bpm. Drilling ahead at 1.47/1.03/3580 psi. 1800 Ibs WOB. IAP=286 psi, OAP=300 psi. Pit vol = 478 bbls. ROP = 12 fph. Still drilling intermittant siderite stringers in the C sand. PROD1 WOB=1300 Ibs, String weight = -9200 Ibs, max snubbing weight. Drilling on another hard siderite stringer. PROD1 Still grinding away on a hard spot. WOB=2000 Ibs, String wt = -7000 Ibs. PROD1 Continue directionally drilling ahead f/ 10874' Q= 1.41 / 1.01 FS= 3460 W06= 2k coil wt= -5.7k slow drilling on siderite stringer PROD1 Drill f/ 10903' to 10920' TD .All shale. PROD1 Wiper trip. 22k clean pick-up. 100psi MW at 10010'- -10000' clean to window. Log tie-in + 2' correction. RIH clean through 9980'-10030' start loading coil with 11.2 KWM clean to bottom. Correct TD 10918' PROD1 TOH pumping KWM. Stop and paint EOP flag at 8350'. TOH following revised pressure schedule. PROD1 Tag up at surface. Check for flow. PROD1 PJSM re BHA rig down. No flow objerved. PROD1 Rig down BHA #9. Bit recovered and graded at 2,2,bt. RUNPRD Reconfigure BHI BHA to run liner. RUNPRD Fill hole, took 1 bbl. Hold PJSM in ops cabin to discuss running liner. Discussed the need to keep the hole full, to have the safety joint ready to go, and to watch out for overhead loads. RUNPRD Begin making up 2-3/8" liner string. Liner run order as follows; Baker Bias Edge Guide shoe 1 jt solid 2-3/8" liner Baker 0-ring sub 16 jts slotted 2-3/8" liner 11 jts solid 2-3/8" liner 40 jts slotted 2-3/8" liner 6 jts solid 2-3/8" liner 2 jts slotted 2-3/8" liner Baker 2-3/8" solid pup jt Baker Deployment sleeve 7/15/2005 20:30 - 20:40 20:40 - 23:20 23:20 - 23:45 23:45 - 00:00 00:00 - 02:00 Total liner BHA length = 2420.51' 0.17 CASE P RUNPRD Hold kick while tripping drill while on joint #3. Good response by all hands. 2.67 CASE P RUNPRD Lay down safety joint, resume running 2-3/8" liner as per proceedure. 0.42 CASE P RUNPRD Make up Baker GS to deployment sleeve, and BHI MWD tool to top of GS. MU coil, and stab injector. 0.25 CASE P RUNPRD RIH with liner on coil tubing. 2.00 CASE P RUNPRD RIH with liner BHA. Weight check at 25 klbs at the window. RIH slick thru the window. Slick down to the open hole sidetrack depth of 9750'. Slowed down to 10 fpm thru the sidetrack and didn't see anything. Slick down thru the trouble spot in the B shale 9995'-10100'. Set down at 10253'. Printed: 7/18/2005 11:19:52 AM BP EXPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: 1 D-42 Common Well Name: 1 D-42 Spud Date: 11/8/2000 Event Name: REENTER+COMPLETE Start: 7/1/2005 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: ate rom - To Hours '~ Code 'I Phase - - -- __ Task ~ N ~ DPRB 5/2005 02:00 - 02:35 0.581 CASE ~ RUNPRD 02:35 - 03:10 I 0.581 CASE I N I DPRB I RUNPRD 03:10 - 03:35 I 0.421 CASE I N I DPRB I RUNPRD 03:35 - 03:50 I 0.251 CASE I N (DPRB I RUNPRD 03:50 - 04:45 I 0.921 CASE I N I DPRB I RUNPRD 04:45 - 05:40 I 0.921 CASE I N I DPRB I RUNPRD 05:40 - 08:30 2.83 CASE N DPRB RUNPRD 08:30 - 08:45 0.25 CASE N RUNPRD 08:45 - 09:05 0.33 CASE N RUNPRD 09:05 - 11:45 2.67 CASE N RUNPRD Description of Operations Possibly setting down at fault picked in sidetrack at 10252'. Also possibly in the original wellbore. Depth of Kalubik shale in original wellbore 10240'. PU at 37 klbs. RIH, set down at 10140'. PU, RIH. String Wt = +3000 Ibs, WOB=5000 lbs. Set down at 10251'. Try picking up string wt plus 10' to get the racheting bottom nose to do its thing. Set down again at 10251'. Repeat 6 times and could not get past 10251'. Try picking up until we just get string wt back, and then running back in the hole. Repeat 12 times with no success. PU last time at 40 klbs. WOB= -15 klbs. Seems heavy on both. Considering the possibility we are in the original lateral, and not the OH sidetrack. Pick up above the sidetrack depth of 9750'. Stop at 9715'. RIH and hope the racheting bottom nose finds the correct hole. RIH at 15 fpm thru 9750' (OH sidetrack depth). String wt=6000 Ibs, WOB= +3000 Ibs. Slight weight bobble at 9750 when running down this time. Sticky thru 10070-10100'. Continue RIH. Set down at 10183'. PU 10', then RIH, set down at 10186'. PU 10', then RIH. Set down at 10184'. PU 100', and RIH at 100 fpm. Set down at 10129'. Try to work it down. Can't make it past 10129' now. Work it 6 times, tag up at 10120'. Might have stirred up some debris that is effecting weight transfer now. Extra drag means we could be at lockup, and not able to get back to original set down depth. Try the Dave Duerr technique. PU weights; WOB=7560 Ibs. CT string wt = -3000 Ibs. Tag up, position coil at neutral wt, Pump 15 bbls, PU, then RIH. Tagged up at 10128'. Repeat again. No luck. Start mixing a 25 bbl piA of Alpine glass beads mixed at 12 Ib/bbl. While waiting for pill to be mixed, pick up above OH sidetrack and try running in the hole again. PU at 37 klbs on string wt, and -14700 Ibs on WOB. RIH at 5 fpm. On line with 25 bbl pill with Alpine beads. Pumping down the coil. Not getting any returns. Pumping at 1.25 bpm, 4300 psi. RIH slowly to keep GS in compression while pumping so we don't release. 13 bbls of beads out of the GS. SI pumps, and open Baker choke. Work the pipe. PU weight 32 klbs, -9000 Ibs on the WOB sensor. RIH, string wt = 4500 Ibs, WOB=4200 lbs. Beads have helped weight transfer. Tag up again at 10249'. Same depth as first set down. May be in old wellbore. PU above OH sidetrack depth of 9750. Up string wt = 32 klbs, W06= -8000 Ibs. Looks like glass beads helped out with wt transfer, but we are still hitting an obstruction. Pick up above OH sidetrack 1 last time, and try RIH. Set down again at 10251'. this appears to be a hard set down depth. It does not appear to be related to wt transfer. This has been a consistent hard bottom. POH Open EDC at 9750' 0= 1.08 / .22 PJSM review plan forward. Review liner handling procedures for standing it back in derrick. Maintaining hole fill with KWM L/D BHi tools. Rack back 38 stands of 2-3/8" liner. Using centrilizers for lift subs and YT elevators. Printed: 7/18/2005 11:19:52 AM • i BP EXPLORATfON Operations Summary Report Legal Well Name: 1 D-42 Common Well Name: 1 D-42 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ', Hours ~ Task ~ Code Start: 7/1 /2005 Rig Release: Rig Number: NPT I Phase Page 10 of 11 Spud Date: 11/8/2000 End: Description of Operations - - ~ _- I 7/15/2005 11:45 - 14:30 2.75 CASE N RUNPRD PU 1-1/2deg Unique bent sub and pup jt. Run back in hole with liner. 14:30 - 14:55 0.42 CASE N RUNPRD MU BHi tools with orienter. Stab injector 14:55 - 18:00 3.08 CASE N RUNPRD RIH no pump. Check weights above window 24.5k up 10k dwn annular psi coinciding with TVD's so not pushing mud away to formation. Window not seen, continue RIH slow to 20'/min from 9720 to 9760' no indication of weight changes continue RIH good indication of shales at 10020-30' (new hole problem area) took wt at 10100' went through ok 4.7k RIH 60'/min setdown at 10204' pu 33k RIH past 10204' and 10250' RIH 10300 4.3k wt setdown at 10340' pu 32k RIH rough go to 10372 setdown. PU 36k RIH to 10374 PU 37k RIH to 10444 with -3 to +1 k wt PU 38k to 10417' RIH stopped at 10444 again. PU try again stopped at 10444' Close choke pump 6bbls got wt back on coil shutdown pump RIH 3k wt (something worked) got to 10504' setdown with -3k start pump again didn't help this time. Dump pressure coil pressure. PU 41 k to 10470 RIH to 10500'. Line up to pump down backside. Pump .5 bpm RIH put 3-400 annular pressure going in better past 10504' 1-3k coil wt pushing going good maintaining 4-500 on annulus setdown at 10665' shutdown pump PU 42k RIH to 10665' PU to 10640' start up pump put 780psi 18:00 - 18:20 0.33 CASE P RUNPRD Made it to 10710', lost ground to 10680'. Looks like we are operating at coil lock up. Mix 10 bbl pill of Alpine glass beads. Made it to 10724'. Continue working pipe. Made it to 10781'. Work pipe some more. Losing ground. 18:20 - 18:30 0.17 CASE P RUNPRD Begin pumping 10 bbl pill of Alpine glass beads down the backside. (All remaining beads on location.) 10 bbls gives 4000' of hole coverage on the backside in 3-1/2" tubing. 2.0 bbls away, made it to 10799'. Continue pumping down the backside, and working pipe. WHP up to 1000 psi. 18:30 - 18:40 0.17 CASE P RUNPRD Made it to EOP flag! EOP flag at 8350' + BHA of 2473.61 = 10823.6'. Found flag at 10838.9'. Make -15' correction. Corrections made during drilling were -10'. PU to 10809'. Kick on pumps down the coil. RIH to liner bottom set depth of 10818'. RIH WOB=1600 lbs.. PU weights previously were 42 klbs. PU weight is 19 klbs. WOB sensor ready -1300 lbs. Confirmed left liner in the hole. 18:40 - 18:50 0.17 CASE P RUNPRD Log tie in pass down with MWD tool. Make a +5' correction. 18:50 - 19:30 0.67 CASE N RREP RUNPRD Schlumberger computer crashed. Spend 40 minutes sorting it out. 19:30 - 19:40 0.17 CASE P RUNPRD RIH using MWD for depth control. SWS depth system inoperative. Tag up on top of liner. Found liner top at 8400.1'. Bottom of liner at 10822.5'. Kick on pumps to ensure GS is released. PU at 19 klbs, W06= -600 lbs. Confirmed liner left in hole on depth. 19:40 - 21:10 1.50 CASE P RUNPRD POH to pick up nozzle to swap well to seawater and FP the well. 21:10 - 21:30 0.33 CASE P RUNPRD Tag up at surface. Check for flow. No flow observed. Break off injector. Rig down BHA #12, liner deployment BHA. All recovered ok. MU nozzle BHA to swap the well to seawater. Circulate seawater to the nozzle. Make up injector to well. 21:30 - 00:00 2.50 CASE P RUNPRD RIH contaminating KWF with seawater. Printed: 7/18/2005 11:19:52 AM BP EXPLORATION Page 11 of 11 Operations Summary Report Legal Well Name: 1 D-42 Common Well Name: 1 D-42 Spud Date: 11/8/2000 Event Name: REENTER+COMPLETE Start: 7/112005 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date ,From - To ;' Hours Task ~ Code NPT Phase Description of Operations ~ 7/16/2005 00:00 - 00:20 0.33 - CASE P } -- RUNPRD - -- -- Continue RIH with nozzle BHA. 00:20 - 00:45 0.42 CASE P RUNPRD Stop at 8300', 100' above top of liner. Circulate bottoms up, holding pressure with choke to ensure that BHP is maintained. 00:45 - 01:50 1.08 CASE P RUNPRD POH following pressure schedule. 01:50 - 02:30 0.67 CASE P RUNPRD Tag up at surface with nozzle BHA. Bullhead 25 bbls of diesel to freeze protect the well. Left 600 psi on wellhead. 02:30 - 03:00 0.50 CASE P RUNPRD Break off injector. Rig down nozzle BHA. 03:00 - 05:00 2.00 RIGD P POST Clean pits, begin rigging down. Nipple down BOP stack. PT tree cap to 500 psi low pressure test and 3500 psi high pressure test. Passed ok. Rig released at 05:00 Further telex entries carried on 1 D-36 morning report. Printed: 7/18/2005 11:19:52 AM Y Conocot~hitlips Baker Hughes INTEQ Baker Hughes INTEQ Survey Report ~T>EC~ Company:.' ConocoPhiilips Alaska, Inc Date: 8/3/2005 Time: 14:58:3T Page: 1 Field: Kuparuk River Unit Co-ordwate(NE) Reference: .Well: 42, True North Site: Pad 1D Vertical (TVD),Reference: Wetlhead(106'j 106.0 Weil: 42 Section (VS) Reference: ':Well (OAON,O:OOE,151.OOAzi) Wellpath: 1 D-42L1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Msp System:US State Plane Coordinate System 1927. Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 D North Slope, Alaska Site Position: Northing: 5959669.52 ft Latitude: 70 18 1.316 N From: Map Fasting: 561086.90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 42 Slot Name: Well Position: +N/-S -566.97 ft Northing: 5959099.20 ft Latitude: 70 17 55.740 N +E/-W -420.75 ft Fasting : 560670.81 ft Longitude: 149 30 31.173 W Position Uncertainty: 0.00 ft Wellpath: 1 D-42L1 Drilled Froro: 1 D-42L1 P61 Tie-on Depth: 9722.58 ft Current Datum: Wellhead(106') Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/18!2005 Declination: 24.27 deg Field Strength: 57607 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 151.00 Survey Program for Definitive Wellpath Date: 7!18/2005 Validated: Yes Version: 0 Actual From To Survey Toolcode Tool Name ft ft 110.00 8400.47 MWD w/IFR<0 - 8660'> (110.00-8660.00) (Oy1WD+SAG+IFR MWD+SAG+IFR (AK) 8414.00 9722.58 MWD (8414.00-10300.00) (1) MWD MWD -Standard 9753.69 10918.00 MWD (9753.69-10918.00) MWD MWD -Standard Annotation MD. . TW ff ft 9722.58 6243.24 TIP 10918.00 6334.29 TD Survey: MWD Start Date: 7/18/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Inc! - Azim TVD ' SS TVD; N/S E/W` MapN MapE VS DLS Tool ft deg deg ft ft ' ft ft ft ft ft degl100ft 9722.58 90.60 109.43 6243.24 6137.24 -5422.58 -625.66 5953672.26 560089.01 4439.37 0.00 MWD 9753.69 84.52 110.33 6244.57 6138.57 -5433.15 -596.44 5953661.94 560118.30 4462.78 19.76 MWD 9783.54 82.72 120.41 6247.89 6141,89 -5445.84 -569.67 5953649.47 560145.17 4486.85 34.10 MWD 9812.74 82.88 125.05 6251.55 6145.55 -5461.49 -545.31 5953634.00 560169.66 4512.36 15.77 MWD 9843.51 81.83 129.30 6255.65 6149.65 -5479.92 -521.02 5953615.78 560194.10 4540.25 14.11 MWD 9873.18 80.79 126.90 6260.13 6154.13 -5498.01 -497.94 5953597.87 560217.32 4567.26 8.73 MWD 9899.91 82.22 122.68 6264.08 6158.08 -5513.09 -476.23 5953582.97 560239.15 4590.98 16.50 MWD 9932.03 81.73 118.11 6268.57 6162.57 -5529.18 -448.81 5953567.11 560266.70 4618.34 14.17 MWD 9962.90 82.63 114.21 6272.77 6166.77 -5542.66 -421.36 5953553.85 560294.25 4643.44 12.85 MWD 9998.46 83.55 109.35 6277.05 6171.05 -5555.75 -388.59 5953541.02 560327.12 4670.78 13.81 MWD 10033.54 84.20 105.28 6280.79 6174.79 -5566.13 -355.30 5953530.92 560360.49 4696.00 11.68 MWD ConocoPhillips Baker Hughes INTEQ Baker Hughes INTEQ Survey Report 11VTE#,2 Company: ConocoPhillips Alaska, Inc 'Date: 8/3/2005 Time: - 14:58:37 Page: 2 .Field: Kuparuk River Unit Go-ordinate(NE) Reference: Well: 42, True North Site:. Pad"tO' Vertical (TVD)Refereuce: Wellhead(106 ') 106.0 Well: 42 Wellpath: 1D-42L1 Section(VS)Refereuce: Survey Calculation Method: Well (O.OON,O.OOE,151.OOAzi) Minimum Curvature Db: Oracle Survey MD Incl. Azim TVD SS TVD N/S E/W MapN MapE VS DLS Toot ft deg deg ft ` ft ft ft ft ft ft deg/100ft 10060.20 82.39 101.42 6283.91 6177.91 -5572.24 -329.54 5953525.01 560386.29 4713.83 15.90 MWD 10091.40 80.14 97.19 6288.65 6182.65 -5577.23 -299.12 5953520.27 560416.75 4732.94 15.22 MWD 10123.43 81.51 100.70 6293.76 6187.76 -5582.15 -267.89 5953515.60 560448.02 4752.38 11.63 MWD 10153.71 81.71 104.48 6298.18 6192.18 -5588.68 -238.66 5953509.31 560477.30 4772.26 12.37 MWD 10182.05 82.35 109.02 6302.11 6196.11 -5596.77 -211.79 5953501.44 560504.23 4792.36 16.02 MWD 10212.87 82.95 110.95 6306.05 6200.05 -5607.21 -183.07 5953491.23 560533.03 4815.43 6.51 MWD 10245.28 84.20 116.85 6309.68 6203.68 -5620.26 -153.64 5953478.43 560562.56 4841.10 18.50 MWD 10281.56 86.36 120.93 6312.67 6206.67 -5637.72 -121.99 5953461.22 560594.35 4871.72 12.69 MWD 10310.46 86.63 124.06 6314.43 6208.43 -5653.22 -97.66 5953445.92 560618.80 4897.07 10.85 MWD 10341.34 86.23 130.14 6316.36 6210.36 -5671.80 -73.09 5953427.54 560643.51 4925.23 19.69 MWD 10367.80 91.64 128.59 6316.85 6210.85 -5688.57 -52.65 5953410.93 560664.09 4949.81 21.27 MWD 10395.29 88.45 125.28 6316.83 6210.83 -5705.09 -30.68 5953394.60 560686.19 4974.91 16.72 MWD 10423.22 86.08 118.97 6318.16 6212.16 -5719.91 -7.07 5953379.96 560709.92 4999.32 24.11 MWD 10454.64 85.22 114.06 6320.55 6214.55 -5733.90 20.96 5953366.21 560738.05 5025.14 15.82 MWD 10483.27 88.63 112.71 6322.08 6216.08 -5745.24 47.19 5953355.08 560764.38 5047.78 12.81 MWD 10514.31 89.46 108.77 6322.60 6216.60 -5756.23 76.21 5953344.33 560793.48 5071.46 12.97 MWD 10549.18 88.97 105.12 6323.08 6217.08 -5766.39 109.56 5953334.44 560826.91 5096.51 10.56 MWD 10580.58 88.57 100.20 6323.75 6217.75 -5773.27 140.18 5953327.81 560857.58 5117.37 15.72 MWD 10610.81 89.28 95.99 6324.32 6218.32 -5777.52 170.10 5953323.79 560887.52 5135.60 14.12 MWD 10641.80 87.90 92.76 6325.08 6219.08 -5779.89 200.98 5953321.68 560918.43 5152.64 11.33 MWD 10675.28 90.17 98.62 6325.65 6219.65 -5783.20 234.27 5953318.63 560951.74 5171.68 18.77 MWD 10703.49 91.95 104.10 6325.13 6219.13 -5788.76 261.92 5953313.30 560979.42 5189.94 20.42 MWD 10732.92 90.51 107.86 6324.49 6218.49 -5796.86 290.20 5953305.43 561007.77 5210.73 13.68 MWD 10767.47 90.45 112.35 6324.20 6218.20 -5808.73 322.63 5953293.82 561040.29 5236.84 13.00 MWD 10795.91 89.71 113.82 6324.16 6218.16 -5819.88 348.79 5953282.88 561066.54 5259.28 5.79 MWD 10827.19 86.39 113.34 6325.23 6219.23 -5832.38 377.44 5953270.61 561095.29 5284.10 10.72 MWD 10861.92 85.16 109.67 6327.79 6221.79 -5845.08 409.66 5953258.18 561127.60 5310.83 11.12 MWD 10890.69 82.72 104.74 6330.83 6224.83 -5853.54 436.98 5953249.94 561154.98 5331.47 19.03 MWD 10918.00 82.72 104.74 6334.29 6228.29 -5860.43 463.17 5953243.26 561181.24 5350.20 0.00 MWD Conoc Phillips Baker Hughes INTEQ Baker Ilughes INTEQ Survey Report "~9~~1 IiVTEQ Company:' ConocoPhillips Alaska, tnc Date: 8/3/2005 Time: 14:57:42 Page: l Field: Kuparuk RiverUnit Co-ordinate(NE) Reference: Welh 42, Ttue North Site: Pad 10 Vertical (TVD) Reference: Wellhead(106')106.0 `Well: 42 Section (VS) Reference: Well (O.OON,O.OOE,151.OOAzi) Wellpath: 1 D-42L1 PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 D North Slope, Alaska Site Position: Northing: 5959669.52 ft Latitude: 70 18 1.316 N From: Map Easting: 561086.90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 42 Slot Name: Well Position: +N/-S -566.97 ft Northing: 5959099.20 ft Latitude: 70 17 55.740 N +E/-W -420.75 ft Easting : 560670.81 ft Longitude: 149 30 31.173 W Position Uncertainty: 0.00 ft Wellpath: 1D-42L1P61 Drilled From: 1D-42 Tie-on Depth: 8303.83 ft Current Datum: Wellhead(106') Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 4/11/2005 Declination: 24.39 deg Field Strength: 57597 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 151.00 Survey Program for Definitive Wellpath Date: 7/11/2005 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 110.00 8400.47 MWD w/IFR<0 - 8660'> (110.00-8660.00) (ayIWD+SAG+IFR MWD+SAG+IFR (AK) 8414.00 10300.00 MWD (8414.00-10300.00) MWD MWD -Standard Annotation MD -' TVD ft ft 8400.47 6226.28 TIP 8414.00 6235.12 KOP 10300.00 6280.10 TD Survey: MWD Start Date: 7/11/2005 Company: Halliburton Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD SS TVD N!S E/W _ MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 8400.47 49.24 197.90 6226.28 6120.28 -4726.53 -1561.87 5954360.67 559147.30 3376.71 0.00 MWD 8414.00 49.16 197.85 6235.12 6129.12 -4736.28 -1565.01 5954350.90 559144.24 3383.71 0.65 MWD 8447.57 58.96 197.58 6254.80 6148.80 -4762.14 -1573.27 5954324.97 559136.19 3402.32 29.20 MWD 8471.05 67.97 197.43 6265.28 6159.28 -4782.15 -1579.58 5954304.91 559130.04 3416.77 38.38 MWD 8500.06 81.81 197.26 6272.82 6166.82 -4808.82 -1587.90 5954278.18 559121.93 3436.06 47.71 MWD 8539.09 91.21 174.75 6275.23 6169.23 -4847.27 -1591.91 5954239.70 559118.23 3467.75 62.34 MWD 8572.78 92.35 159.00 6274.17 6168.17 -4879.97 -1584.29 5954207.07 559126.12 3500.03 46.85 MWD 8606.93 90.91 156.25 6273.20 6167.20 -4911.53 -1571.30 5954175.62 559139.37 3533.94 9.09 MWD 8637.52 91.92 152.45 6272.45 6166.45 -4939.09 -1558.06 5954148.17 559152.82 3564.46 12.85 MWD 8668.32 91.34 149.09 6271.57 6165.57 -4965.95 -1543.03 5954121.43 559168.07 3595.24 11.07 MWD 8700.42 92.16 146.62 6270.59 6164.59 -4993.12 -1525.96 5954094.41 559185.35 3627.28 8.10 MWD /.. ConocoPh~ll~ps Baker Hughes INTEQ Baker Hughes INTEQ Survey Report ~i~t _ ~ ICVTE(Z Company: ConocoPhillips'Alaska, Inc Date: 8/3!2005 Time: 14:57:42 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 42, True North Site: Pad tD Vertical (1'VD) Reference: Wellhead(106')106.0 Welt: 42 Section (VS) Reference: Well (O.OON,O.p0E,151.00Azi) VVellpath: 1D-42L1PBt Survey Calculation Method: Minimum Curvatun: Db: Oracle Survey MD Inc! Azim TVD SS TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft $ ft ft ft ft ft deg/100ft 8736.69 91.37 143.22 6269.47 6163.47 -5022.78 -1505.13 5954064.92 559206.42 3663.32 9.62 MWD 8770.00 91.55 139.74 6268.62 6162.62 -5048.83 -1484.39 5954039.04 559227.37 3696.16 10.46 MWD 8805.50 92.90 135.45 6267.24 6161.24 -5075.02 -1460.48 5954013.05 559251.49 3730.65 12.66 MWD 8835.54 91.67 132.50 6266.05 6160.05 -5095.85 -1438.88 5953992.38 559273.25 3759.35 10.63 MWD 8866.03 92.84 128.59 6264.85 6158.85 -5115.65 -1415.73 5953972.77 559296.56 3787.89 13.38 MWD 8904.99 93.55 124.40 6262.67 6156.67 -5138.78 -1384.47 5953949.90 559328.00 3823.28 10.89 MWD 8937.66 93.12 121.14 6260.77 6154.77 -5156.44 -1357.05 5953932.47 559355.56 3852.01 10.05 MWD 8970.95 92.78 118.11 6259.06 6153.06 -5172.87 -1328.15 5953916.27 559384.59 3880.39 9.15 MWD 9001.04 92.59 114.82 6257.65 6151.65 -5186.26 -1301.25 5953903.10 559411.60 3905.15 10.94 MWD 9028.12 90.05 110.27 6257.03 6151.03 -5196.64 -1276.25 5953892.93 559436.67 3926.34 19.24 MWD 9057.56 89.68 107.99 6257.10 6151.10 -5206.28 -1248.44 5953883.51 559464.56 3948.26 7.85 MWD 9087.22 91.46 104.15 6256.80 6150.80 -5214.49 -1219.95 5953875.53 559493.11 3969.25 14.27 MWD 9117.85 90.68 102.46 6256.23 6150.23 -5221.54 -1190.15 5953868.72 559522.97 3989.87 6.08 MWD 9149.13 92.04 99.58 6255.49 6149.49 -5227.52 -1159.46 5953862.99 559553.70 4009.97 10.18 MWD 9180.32 94.19 97.62 6253.79 6147.79 -5232.17 -1128.67 5953858.59 559584.53 4028.97 9.32 MWD 9210.73 91.98 96.29 6252.15 6146.15 -5235.85 -1098.53 5953855.15 559614.69 4046.80 8.48 MWD 9240.89 93.36 99.49 6250.75 6144.75 -5239.98 -1068.69 5953851.26 559644.56 4064.88 11.54 MWD 9269.51 91.15 100.56 6249.62 6143.62 -5244.96 -1040.53 5953846.51 559672.76 4082.89 8.58 MWD 9308.06 89.43 104.86 6249.43 6143.43 -5253.44 -1002.93 5953838.34 559710.41 4108.53 12.01 MWD 9337.42 91.67 107.69 6249.15 6143.15 -5261.67 -974.76 5953830.34 559738.65 4129.39 12.29 MWD 9369.61 92.96 110.63 6247.84 6141.84 -5272.22 -944.38 5953820.03 559769.11 4153.35 9.97 MWD 9400.57 92.69 113.82 6246.32 6140.32 -5283.92 -915.76 5953808.57 559797.83 4177.45 10.33 MWD 9426.78 92.22 116.80 6245.20 6139.20 -5295.11 -892.09 5953797.57 559821.58 4198.72 11.50 MWD 9459.77 89.16 118.27 6244.80 6138.80 -5310.36 -862.84 5953782.56 559850.95 4226.23 10.29 MWD 9489.76 90.32 116.89 6244.93 6138.93 -5324.24 -836.26 5953768.89 559877.64 4251.26 6.01 MWD 9520.15 91.79 117.58 6244.38 6138.38 -5338.15 -809.25 5953755.20 559904.76 4276.52 5.34 MWD 9549.75 91.98 118.82 6243.40 6137.40 -5352.13 -783.17 5953741.44 559930.94 4301.39 4.24 MWD 9586.61 90.02 118.11 6242.76 6136.76 -5369.69 -750.78 5953724.14 559963.48 4332.46 5.66 MWD 9616.80 88.42 114.64 6243.17 6137.17 -5383.10 -723.74 5953710.95 559990.62 4357.29 12.66 MWD 9650.25 90.57 113.40 6243.46 6137.46 -5396.71 -693.19 5953697.58 560021.28 4384.01 7.42 MWD 9692.17 89.77 110.19 6243.34 6137.34 -5412.28 -654.27 5953682.34 560060.32 4416.49 7.89 MWD 9722.58 90.60 109.43 6243.24 6137.24 -5422.58 X25.66 5953672.26 560089.01 4439.37 3.70 MWD 9749.82 89.00 108.15 6243.34 6137.34 -5431.36 -599.87 5953663.70 560114.86 4459.55 7.52 MWD 9787.23 90.38 105.80 6243.54 6137.54 -5442.28 -564.10 5953653.07 560150.72 4486.44 7.28 MWD 9817.25 89.62 105.50 6243.54 6137.54 -5450.37 -535.19 5953645.20 560179.69 4507.54 2.72 MWD 9847.97 88.91 104.73 6243.93 6137.93 -5458.38 -505.53 5953637.44 560209.41 4528.92 3.41 MWD 9882.01 88.33 104.69 6244.75 6138.75 -5467.03 -472.62 5953629.06 560242.39 4552.44 1.71 MWD 9917.97 91.61 106.27 6244.77 6138.77 -5476.62 -437.97 5953619.75 560277.11 4577.63 10.12 MWD 9952.97 88.02 109.49 6244.88 6138.88 -5487.36 -404.67 5953609.27 560310.49 4603.17 13.78 MWD 9982.15 88.51 113.17 6245.77 6139.77 -5497.97 -377.51 5953598.89 560337.74 4625.62 12.72 MWD 10008.62 88.42 115.60 6246.48 6140.48 -5508.90 -353.41 5953588.16 560361.92 4646.85 9.18 MWD 10035.91 86.76 118.43 6247.63 6141.63 -5521.28 -329.12 5953575.97 560386.30 4669.46 12.01 MWD 10063.80 84.48 119.41 6249.76 6143.76 -5534.72 -304.78 5953562.73 560410.75 4693.02 8.89 MWD 10093.65 83.55 123.79 6252.87 6146.87 -5550.28 -279.50 5953547.38 560436.15 4718.87 14.92 MWD 10119.84 83.65 125.89 6255.79 6149.79 -5565.14 -258.14 5953532.69 560457.63 4742.23 7.98 MWD 10153.96 83.28 129.63 6259.67 6153.67 -5585.90 -231.35 5953512.15 560484.59 4773.38 10.94 MWD 10190.28 81.73 133.59 6264.41 6158.41 -5609.80 -204.43 5953488.47 560511.69 4807.33 11.62 MWD 10221.22 81.05 132.08 6269.04 6163.04 -5630.60 -182.00 5953467.85 560534.29 4836.40 5.30 MWD 10249.46 83.49 129.99 6272.84 6166.84 -5648.97 -160.89 5953449.66 560555.54 4862.70 11.33 MWD 10300.00 80.00 127.00 6280.10 6174.10 -5680.10 -121.76 5953418.85 560594.92 4908.90 9.05 MWD ( ~f TUBING (o~osa, OD:3.500, ID:2.992) LINER (8oo1-8aoo, OD:3.500) LOCATOR (aols~ol7, oD:s.1 zs> Blank Pipe (8401-8411, OD:2.390) Perf (san-aa7s> Blank Pipe (8475665, OD:2.375) Perf (8665-9934) Blank Pipe (9934-10280, OD:2.375) Perf ;1o2BO-1o7s8> ConocoP'hillips Alaska, Inc. KRU D-42L1 1D-42L1 -- __ API: 500292297960 Well T e: PROD An le TS: de SSSV Type: NIPPLE Orig Completion: Angle @ TD: deg @ 10918 Annular Fluid: Last W%O: _ Rev Reason: NEW WELL Reference Lo : 28.96' RKB - Ref Lo Date: _ Last U date: 8/5/2005 Last Ta TD: 8660 ftKB Last Tag Date: Max Hole An le: 0 deg _ Casin String -COMMON STRINGS Descri lion Size To Bottom TVD Wt Grade Thread PRODUCTION 7.000 0 8188 8188 26.00 L-80 BTCMOD CONDUCTOR 20.000 0 91 91 91.50 H-40 WELDED ` ` SURFACE _ _ 9.625 0 _ 5312 _ 5312 40.00 _ L-80 BTCMOD ~ WINDOW I 3.500 8400 8401 8401 0.00 Casin Strin - L1 LINER Altematin blank i e & slotted liner - to in L1 I Descri lion _ _ Size Top Bottom TVD Wt Grade Thread SLOTTED LINER 2.375 __ 8400 10822 10822 4.60 L-80 STL Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 8054 8054 9.30 L-80 EUE8rd Perforations Summa 1 Interval TVD Zone Status Ft SPF Date T e Comment 8411 - 8475 8411 -8475 64 40 7/15/2005 IPERF Slotted Tubing alternating w/blank i 8665 - 9934 8665 - 9934 1269 40 7/15/2005 IPERF Slotted Tubing alternating w/blankpipe 10280 - 10788 10280 - 10788 508 40 7/15/2005 IPERF - _ Slotted Tubing alternating w/blank i Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type _ _ V Mfr V Type V OD Latch _ Port TRO Date Run Vlv Cmnt 1 2653 2653 CAMCO KBUG GLV 1.0 BK 0.156 1280 7/19/2005 2 4840 4840 CAMCO KBUG GLV 1.0 BK5 0.188 1305 7/19/2005 3 6236_ 6236 CAMCO KBUG GLV 1.0 BK5 0.250 1395 7/18/2005 4 7151 7151 CAM_CO KBUG GLV 1.0 BK5 _ 0.250 1375 7/18/2005 5 7920 7920 CAMCO KBUG __ _ OV 1.5 _ BK5 _ 0.188 _ 0 7/18/2005 Other lu s e ui .etc. -COMMON JEWELRY ~ De th TVD T e Descri lion ID 512 512 NIP CAMCO'DS' NIPPLE w/NO GO PROFILE 2.875 7972 7972 NIP CAMCO 'DS' NIPPLE w/NO GO PROFILE 2.812 8001 8001 Tie Back Sleeve BAKER TIE BACK SLEEVE 4.537 8001 8001 LINER UPPER PORTION OF MAIN LEG 1D-42 LINER 2.992 8008 8008 PACKER BAKER ZXP LINER TOP PACKER 4.375 8016 8016 LOCATOR BAKER NO GO LOCATOR 3.000 8017 8017 SEAL BAKER GBH-22 SEAL ASSEMBLY 3.000 8087 8087 _ NIP HALLIBURTON 'XN' NIPPLE 2.813 8414 8414 Whi stock WEATHERFORD LSX-N FLOW-THRU WHIPSTOCK 0.000 Other lu s e ui ., etc. - L1 LINER JEWELRY To of liner in Lateral L1 De th TVD T e Descri lion ID 8400 8400 Deploy Sleeve BTT SEAL BORE DEPLOYMENT SLEEVE w/3" GS PROFILE IN L1 LINER 1.920 8401 8401 Blank Pi 1.920 8475 8475 Blank Pie 1.992 9934 9934 Blank Pipe 1.992 10787 10787 O-RING BBB O-RING SUB 1.000 _ I t 10788 10788 Blank Pi 1.000 -_ 10821 10821 SHOE UNIQUE BIAS EDGE INDEXING GUIDE SHOE 0.000 -- -- General Notes Date Note 7/15/2005 MULTI-LATERAL WELL: MAIN LEG 1D-42 LATERAL LEG 1D-42L1 = I I = ~ ~ 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submitto: .E3E'3...f~'g~~~~r~i~3__s~~tf ~x_ u t,~e~~(.':; ~~E.E~~I E?£? }3r'~r'ct`~~.r$i~'~fY3f~.:i'~~~F'.iC ~`i_E_e~a C~1:~...5~£?;;~E-`.-f1S#£?ifA,`r"U ~~f~"Ei63 _Sfc~_~f _~?C _~!S Contractor: Nordic Rig No.: 2 DATE: 7/3/05 Rig Rep.: Mckeirnan / Dowell Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Goodrich / Sevcik E-Mails~~~c~:~~c~rl~rE~_:~ic"fc?~I~?u~(~ftr~~~~?_~.~r3 Well Name: 1 D-42 L1 PTD # 205-078 Operation: Drlg: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 400/3500 Annular: 400/3000 Valves: 400/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NT Housekeeping: P Drl. Rig P Lower Kelly NT PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NT BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2" P Trip Tank P P Annular Preventer 1 7 1/16" FP Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve 0 N/A NA Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2000 P Quantity Test Result 200 psi Attained 20 sec P No. Valves 14 P Full Pressure Attained 100 sec P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4@ 2100 Test Results Number of Failures: 1 Test Time: 9 Hours Components tested 29 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: l3E"~..-rE~g~ ~~~s~i~3._~~~_kf.~~.~ Remarks: Annular failed changed out element and retest ok Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES XXX NO c - Oper./Rig Waived By c -Database Date 7/2/05 Time 0700 c -Trip Rpt File Witness Chuck Scheve c -Inspector Test start 0000 Finish 0900 Coil Tubing BFL 11/09/04 Nordic 2 BOP 7-3-05.x1s ~ ~ ` ~ ~ ~ ~ ~ ~ ~{ ~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~ ~ ~ ~ *_ ~~r~ ~~ ~~++ ~~ ~~ ~D v~17 , 333 W. 7"' AVENUE, SUITE 100 C01~5ERQA'1'IU1Q CUMl~'IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Aras Worthington CT Drilling Engineer ConocoPhillips Alaska Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk 1 D-42L 1 ConocoPhillips Alaska Inc. Permit No: 205-078 Surface Location: 567' FNL, 421' FEL, SEC. 23, T11N, R10E, UM Bottomhole Location: 1091' FNL, 60' FWL, SEC. 25, T11N, R10E, UM Dear Mr. Worthington: Enclosed is the approved application for permit to redrill the above development well. The permit is for a new wellbore segment of existing well KRU 1II-42, Permit No.200-164, API No. 50-029-22979-00. Production should continue to be reported as a function of the original API number stated above. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this .permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to ess any required test. Contact the Commission's petroleum field inspector a~09-3~ger). DATED this~day of May, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ` G~S-ZD - pf STATE OF ALASKA ~ ALAS~OIL AND GAS CONSERVATION G~i~IIMISSl01~~ PERMIT TO DRILL ~° ~Iqy ~ ~ 2Q05 1 ~~ 20 AAC 25.005 Sl2° /~ . 1a. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ® tti one ^ Stratigraphic Test ^ Service ^ Development ~ le Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: 1 D-42L1 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD ~ 11000 TVD 6209ss 12. Field /Pool(s): Kuparuk River Field /Kuparuk 4a. Location of Well (Governmental Section): Surface:~~ 567''3NL 421'~EL SEC 23 Ti 1 N R10E UM ~ 7. Property Designation: ADL 025661 ~ River Pool , , , , . , Top of Productive Horizon: 1989' WEL, SEC. 26, T11 N, R10E, UM ~ 26' SNL~~ 8. Land Use Permit: 13. Approximate Spud Date: June 20, 2005 ~~ Total ITepth: fi 1091' SNL, 60' E1NL, SEC. 25, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 7700' `~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 560671 ~ y- 5959099 ~ Zone- ASP4 10. KB Elevation (Height above GL): 105 feet t5. Distance to Nearest well Within Pool 1 D-07 offset by 1960' ' 16. Deviated Wells: Kickoff Depth: 8415 ~ feet Maximum Hole Angle: 97 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3500 Surface: 2880' 18. asing rogram: Size Specifications Setting Depth To Bottom uantity o ' ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 2595' 8405' 6120' 11000' 6209' Uncemented Slotted Liner 19. PRESENT W ELL CONDITION SUMMARY (To be completed for R®drilL AND Re-entry Operations) Total Depth MD (ft): 8660 Total Depth TVD (ft): 6399 Plugs (measured): None Effective Depth MD (ft): 8593 Effective Depth TVD (ft): 6354 Junk (measured): None Casin Len th Size Cement Volume MD TVD r rl C r 115' 20" 50 sx Arcticset I 115' 115' 5312' 9-5/8" 00 sx AS III Lite, 350 sx LiteCRETE 5312' 4225' 8188' 7" 170 sx Class 'G' 8188' 6089' ro i n 659' 3-1/2" 172 sx Class 'G' 8001' - 8660' 5967' - 6399' Perforation Depth MD~(ft): 8430' - 8460' f~' Perforation Depth TVD (ft): 6246' - 6265' 20. Attachments ~ fling Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis [~ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 265-6802 Printed Name Aras Worthington Title CT Drilling Engineer Lamar antt, 564-5593 ~ Prepared By Name/Number: Si nature .~~L f , ~'ir"~. Phone 265-6802 / 240-5780 Date. ~l t? ~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: k~'J~'~7~ API Number: 50-029-22979-60-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Sampl R wired ^ Yes ~No Mud Log Required ~~~ Yes ~No Hyd gen ulfide Measures \\~Yes rl No Directional Survey Required 'Yes !~~ No Other: 35~ S~ s~' c-4 e~~hhCU APPROVED BY x ~ O~ A roved THE COMMISSION Date cvJ Form 10-401 `ReGisedb6/2db~ \ ., ~ ~ ~ ''--- ~Submif/In Duplicate KRU 1 D-42L1 Sidetrack - Coilebing Drilling Summary of Operations: Coiled tubing drilling will drill l lateral in producer KRU 1D-42 using Dynamically Overbalanced pressure. drilling technique (DOBCTD, see description below). This horizontal laterals will target Kuparuk C sand ~'" reserves for production. The Kuparuk C Sand perforations in the existing well, 1D-42, will be retained. - CTD Drill and Complete 1D-42L1 program: Planned for .Tune 20, 2005 1. Pre CTD MIT-IA, MITT 2. Pre CTD test MV & SV 3. Pre CTD drift tubing/liner with dummy whipstock 4. Pre CTD set whipstock @ 8415' md. 5. MIRU Nordic 2. NU 7-1/16" BOPE, test. 6. Mi112.74" window at 8415' and and 10' of openhole. 7. Dri113" bicenter hole horizontal. lateral from window to 11,000' TD targeting Kuparuk C sands. '' 8. Kill well w/ brine & Complete with 2 3/8" slotted liner from TD 11,000', up into the 3 1/2" liner to -~ 8405' . 9. ND BOPE. RDMO Nordic 2. 10. Post CTD rig -Run GLVs. BOL. Mud Program: • Step 6: 8.6 ppg Chloride based biozan mud • Steps 7: Chloride based Flo-Pro (8.8 ppg) • Steps 8: Viscosified potassium formate KWF (10.2 ppg estimated) Disposal: • No annular injection on this well. ~ • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drillsite 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1D-42L1: 2 3/8", 4.6#, L-80, STL slotted liner from 8405' and to 11.,000' and ` Well Control: o ,. • Two wellbore volumes 0190 bbls) of KWF will be~location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional See attached directional plans for 1D-42L1 Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. f' The nearest well to 1D-42L1 is 1D-07, which is offset by 1960'. KRU boundary is 7700' away. Logging • MWD Gamma Ray will be run. Hazards , • Higher pressure (3500 psi) may be encountered after crossing a mapped fault. • Well 1D-42 has a H2S reading of 106 ppm. 1B is an H2S pad, the highest H2S measurement on the pad is 120 ppm. All H2S monitoring equipment will be operational. .. Reservoir Pressure • KRU 1 D-42L1 Sidetrack - Coile~ubing Drilling • The drilling plan includes crossing a fault where the expected pressure may be 3500 psi at 6236' TVD, 10.8 ppg EMW. "Max. surface pressure with gas (0.1 psi/ft) to surface is 2880 psi. ~ DOBCTD Pressure Drilling Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 8.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability i Applying annular friction and choke pressure also allow use of less expensive drilling fluid and. minimizes fluid losses and/or fracturing at the end of the long wellbores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipelslips (2-3/8" rams, see attached BOP configuration). This well does not have a functional sub-surface safety valve. The annular preventer will act as a secondary barrier during deployment and not as a stripper. Estimated reservoir pressure: 3200 psi at 6236' TVD, 9.9 ppg EMW. ' Expected annular friction losses while circulating: 770 psi. Planned mud density: 8.8 ppg equates to 2850 psi hydrostatic bottom hole pressure. While circulating 8.8 ppg fluid bottom hole circulating pressure is estimated to be 3620 psi or 11.2 ppg ECD. ~ When circulation is stopped, a minimum of 770 psi surface pressure will be applied to maintain constant BHP. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The production liner will be deployed by swapping the ' wellbore to the KWF that not only overbalances the well but is found to work best with the exposed shales during the drilling operation (estimated weight = 10.2 ppg for 100 psi overbalance) -~ • • KRU 1 D-42 ConocoPhillips Alaska, Inc. ~' 1 D-42 API: 500292297900 Well T e: PROD An le TS: 49 de 8414 SSSV Type: NIPPLE Orig COm letion: 11/8/2000 Angle @ TD: 48 deg @ 8660 NIP (512-513, OD:3 500) Annular Fluid: Last W/O: Rev Reason: TAG FILL . ruBING Reference Lo Ref Lo Date: Last U date: 2/27/2004 (o-aosa, Last Ta : 8514 TD: 8660 ftKB oD:3.5o0, ID 2 992 Last Ta Date: 2/1/2004 Max Hole An le: 51 d 4846 : . ) Casin Strin -ALL Descri lion Size To Bottom TVD Wt Grade Thread Gas Lift i CONDUCTOR 20.000 0 91 91 91.50 H-40 WELDED MandrelNalve 1 SURF CASING 9.625 0 5312 4225 40.00 L-80 BTC MOD (2653-2654, PROD CASING 7.000 0 8188 6089 26.00 L-80 BTC MOD LINER 3.500 8001 8660 8660 9.30 L-80 SLHT Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread Gas Lin 3.500 0 8054 6002 9.30 L-80 EUE 8RD MaMrelNalve Perforations Summa 2 Interval TVD Zone Status Ft SPF Date T e Comment (aaaoae4l, 8430 - 8460 6246 - 6265 C-4,C-1 30 6 2/23/2001 IPERF 2.5" HSD 60 d hase Stimulations & Treatments Interval Date T e Comment 8430 - 8460 3/22/2001 FRAC INITIAL'C' SAND FRAC Gas Lin MandrelNalve ~ Gas Lift MandrelsNalves 3 (s236Fi237, St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2653 2498 CAMCO KBUG CAMCO GLV 1.0 BK 0.156 1220 3/26/2001 2 4840 3922 CAMCO KBUG CAMCO GLV 1.0 BK5 0.188 1258 3/26/2001 3 6236 4822 CAMCO KBUG CAMCO OV 1.0 BK5 0.250 0 3/26/2001 Gas Lift 4 7151 5415 CAMCO KBUG CAMCO DMY 1.0 BK5 0.000 0 11/7/2000 3ndrellDummy 5 7920 5915 CAMCO MMG CAMCO DMY 1.5 0.000 0 2/21/2001 valoea (7151-7152 Other lu s e ui etc. -ALL , oD:s.3so) De th TVD T e Descri lion ID 512 512 NIP Camco'DS' Ni le w/No-Go rofile 2.875 7972 5949 NIP Camco'DS'Ni lew/No-Go rofile 2.812 Lift G 8008 5972 PKR Baker ZXP Packer RUN 11/5/00 4.375 as 3ndrel/Dummy 8017 5978 SEAL Baker GBH-22 Seal Assembl 3.000 ValoeS 8087 6023 NIP HAL'XN' Ni le 2.750 (7szo-7x21' OD:5 390) 8658 6397 SHOE Baker Float Shoe 0.000 . General Notes Date Note 2/21/2001 PRESSURE TEST TUBING TO 3000# NIP (7972-7973, OD~.5.390) PKR (8008-8009, OD:5.500) SEAL (8017-8018, OD:4.000) NIP (8087-8088, OD:4.250) FRAC (8430-8460) Pert (8430-8460) _ KRU 1 D-42L1 Producer Proposed Completion 3-1 /2" Camco DB nipple, 2.875" min ID at 512' MD 3-1/2" 9.3# L-80 EUE 8rd Tubing ConocoPhilti s p Alaska, Inc. 3-'/" Camco KBUG GLM @ 2653', 4840', 6236', S 7151', MMG GLM @ 7920' MD . 9-5/8" 40# L-80 ~ 5312' ~^ 2s# L-so 8188' MD ~ L1 KOP 8415' MD Window in 3-1 /2" C4 Sands C4/C1 Sand perfs 3-%" Camco DS nipple, 2.812" min ID @ 7972' MD Baker ZXP Packer w/SBE @ 8,008' MD 2-3/8" Saker deployment sub @ 8405' and 3" openhole 3-%2" LSX WS 2-318" slotted liner 1D-42L1 Lateral, TD @ 11,000' and 100' Blank section set across shale section before fault 3-1 /2" 9.3# L-80 Fill asso' MD 03/25/05 Conoc~tiliips Baker Hughes INTEQ '~°~ Baker Hughes INTEQ Planning Report ~.,~-~;r~ Company: ConocoPhillips Alaska, Inc Date: 4/12/2005 Time: 09:34:50 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 42, True North Site: Pad 1D Vertical (TVD)Reference: Wellhead(106') 106.0 WeII: 42 Section(VS)13eference: Well (O.OON,O.OOE,151. OOAzi) R'ellpath: Plan#5, 1 D-42L1 Survey Calculation Methpd: Minimum Cuwature Db: Oracle I Targets Map Map <___ Latitude --> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1 D-41 L1 Polygon 106.00 -4721.82 -1609.13 5954365.00 559100.00 70 17 9.299 N 149 31 18.052 W -Polygon 1 106.00 -4721.82 -1609.13 5954365.00 559100.00 70 17 9.299 N 149 31 18.052 W -Polygon 2 106.00 -5101.47 -1658.21 5953985.00 559054.00 70 17 5.565 N 149 31 19.479 W -Polygon 3 106.00 -5281.87 -1363.62 5953807.00 559350.00 70 17 3.791 N 149 31 10.896 W -Polygon 4 106.00 -5642.72 -520.43 5953453.00 560196.00 70 17 0.244 N 149 30 46.333 W -Polygon 5 106.00 -6051.02 500.41 5953053.00 561220.00 70 16 56.228 N 149 30 16.597 W -Polygon 6 106.00 -6108.90 1104.02 5953000.00 561824.00 70 16 55.658 N 149 29 59.016 W -Polygon 7 106.00 -5773.88 1106.72 5953335.00 561824.00 70 16 58.953 N 149 29 58.935 W -Polygon 8 106.00 -5594.64 -33.98 5953505.00 560682.00 70 17 0.717 N 149 30 32.163 W -Polygon 9 106.00 -5328.45 -425.88 5953768.00 560288.00 70 17 3.334 N 149 30 43.579 W -Polygon 10 106.00 -4953.69 -1380.98 5954135.00 559330.00 70 17 7.019 N 149 31 11.404 W -Polygon 11 106.00 -4735.51 -1523.23 5954352.00 559186.00 70 17 9.165 N 149 31 15.549 W -Polygon 12 106.00 -4721.82 -1609.13 5954365.00 559100.00 70 17 9.299 N 149 31 18.052 W 1 D-42L1 Fault 1 106.00 -4856.93 -606.10 5954238.00 560104.00 70 17 7.972 N 149 30 48.830 W -Polygon 1 106.00 -4856.93 -606.10 5954238.00 560104.00 70 17 7.972 N 149 30 48.830 W -Polygon 2 106.00 -5920.07 -481.66 5953176.00 560237.00 70 16 57.516 N 149 30 45.203 W 1D-42L1 Fault 3 106.00 -5274.81 -1370.57 5953814.00 559343.00 70 17 3.861 N 149 31 11.099 W -Polygon 1 106.00 -5274.81 -1370.57 5953814.00 559343.00 70 17 3.861 N 149 31 11.099 W -Polygon 2 106.00 -6382.12 12.67 5952718.00 560735.00 70 16 52.972 N 149 30 30.804 W 1 D-42L1 Fault 2 106.00 -4748.78 -251.18 5954349.00 560458.00 70 17 9.036 N 149 30 38.490 W -Polygon 1 106.00 -4748.78 -251.18 5954349.00 560458.00 70 17 9.036 N 149 30 38.490 W -Polygon 2 106.00 -6323.38 46.15 5952777.00 560768.00 70 16 53.549 N 149 30 29.829 W 1 D-42L1 Fault 4 106.00 -5638.05 139.69 5953463.00 560856.00 70 17 0.290 N 149 30 27.104 W -Polygon 1 106.00 -5638.05 139.69 5953463.00 560856.00 70 17 0.290 N 149 30 27.104 W Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Pad 1 D North Slope, Alaska Site Position: Northing: 5959669.52 ft Latitude: 70 18 1.316 N From: Map Easting: 561086.90 ft Longitude: 149 30 18.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.47 deg Well: 42 Slot Name: Well Position: +N/-S -566.97 ft Northing: 5959099.20 ft Latitude: 70 17 55.740 N +E/-W -420.75 ft Easting : 560670.81 ft Longitude: 149 30 31.173 W Position Uncertainty: 0.00 ft Wellpath: Plan#5, 1 D-42L1 Drilled From: 1 D-42 Tie-on Depth: 8303.83 ft Current Datum: Wellhead(106') Height 106.00 ft Above System Datum: Mean Sea Level Magnetic Data: 4/11/2005 Declination: 24.39 deg Field Strength: 57597 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 151.00 Plan: Plan #5 Date Composed: 4/11/2005 Version: 1 Principal: Yes Tied-to: From: Definitive Path ConocoPl~tillips • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~ ~4 Company: ConocoPhillips Alaska, Inc Date: 4/12/2005 Time: 09:34:50 Page: 2 Field: Kuparuk River Unit Co-or dinate(NE) Reference: Well: 42, True North Site: Pad 1D Vertical (TVD)Reference: Wellhead(106') 106.0 ~ Well: 42 Reference: Well (O.OON,O,OOE,151 Section (VS) .OOAzi) Wellpath: Plan#5, 1 D- 42L1 Sun~e y Calculation Method: M inimum Curvature Db: Oracle Targets Name Description 'IV D +N/-S +E/-W Map ~fap Northing Easting <--- Latitude ---> Deg Min Sec <--- Longitude --> Deg Min Sec Dip. Dir. ft ft ft ft ft -Polygon 2 106. 00 -5804. 32 1533.53 5953308. 00 562251.00 70 16 58.653 N 149 29 46.503 W 1 D-42L1 Target#2 6247. 00 -5549. 35 -317.65 5953548. 00 560398.00 70 17 1.162 N 149 30 40.426 W 1 D-42L1 Target#1 6269. 00 -4876. 15 -1198.33 5954214. 00 559512.00 70 17 7.782 N 149 31 6.083 W 1D-42L1 Target#3 6327. 00 -5969. 84 851.11 5953137. 00 561570.00 70 16 57.026 N 149 30 6.382 W Annotation MD "FVD ft ft 8303.83 6163.61 TIP 8415.00 6235.78 KOP 8430.00 6245.45 End of 9°1100' DLS 8517.78 6274.53 4 8562.78 6271.65 5 9037.78 6236.98 6 9187.78 6238.53 7 9487.78 6243.99 8 9687.78 6246.72 9 9787.78 6248.51 10 10037.78 6253.91 11 10087.78 6256.26 12 10362.78 6278.57 13 10462.78 6286.91 14 10662.78 6300.66 15 10962.78 6313.73 16 11000.00 6315.01 TD Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 8303.83 49.90 196.51 6163.61 -4656.26 -1540.11 0.00 0.00 0.00 0.00 8400.47 49.24 197.90 6226.28 -4726.53 -1561.87 1.29 -0.68 1.44 122.40 8415.00 49.15 197.84 6235.78 -4737.00 -1565.24 0.69 -0.62 -0.41 206.76 8430.00 50.50 197.84 6245.45 -4747.91 -1568.75 9.00 9.00 0.00 0.00 8517.78 90.00 197.84 6274.53 -4825.00 -1593.56 45.00 45.00 0.00 0.00 8562.78 97.29 178.90 6271.65 -4869.19 -1600.09 45.00 16.19 -42.10 291.50 9037.78 89.99 107.81 6236.98 -5224.35 -1334.25 15.00 -1.54 -14.97 267.50 9187.78 88.84 85.33 6238.53 -5241.40 -1186.20 15.00 -0.76 -14.98 267.00 9487.78 89.18 130.34 6243.99 -5330.93 -907.95 15.00 0.11 15.00 90.00 9687.78 89.29 100.34 6246.72 -5415.54 -729.27 15.00 0.05 -15.00 270.00 9787.78 88.67 85.35 6248.51 -5420.48 -629.69 15.00 -0.62 -14.99 267.50 10037.78 88.94 122.85 6253.91 -5480.30 -391.59 15.00 0.11 15.00 90.00 10087.78 85.67 129.61 6256.26 -5509.79 -351.33 15.00 -6.55 13.51 116.00 10362.78 85.43 88.23 6278.57 -5596.77 -97.65 15.00 -0.09 -15.05 268.00 10462.78 85.07 103.28 6286.91 -5606.73 1.21 15.00 -0.36 15.05 92.00 10662.78 87.23 133.27 6300.66 -5700.22 174.89 15.00 1.08 15.00 87.00 10962.78 88.04 88.24 6313.73 -5803.69 448.01 15.00 0.27 -15.01 270.00 11000.00 88.04 93.83 6315.01 -5804.36 485.19 15.00 0.00 15.01 90.08 Cc~n©coPhillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report tc~ ~~~+~ Company: GonocoPhillips Alaska, Inc Date: 4!12/2005 Time: 09:34:50 Page: 3 Field: Kup aruk Rlver Unit Co-ordiaate(NE) Re ference: Well: 42, Tr ue North Site: Pad 1D Vertical (T'VI)) Reference: Wellh ead(106') 106.0 R'ell: 42 Section (VS)13eference: Well (O.OON ,O.OOE,151 .OOAzi) i Wellpath: Plan#5, 1 D- 42L1 Survey Calculation Method_ Minim um Cu rvature Db : Oracle SUR'ey hfD Inc! Azim SS TVD N/S E/W MapN 11IapE DLS VS TFO '1'001 ft deg deg ft ft ft ft ft deg /100ft ft deg 8303. 83 49. 90 196.51 6057.61 -4656. 26 -1540. 11 5954431. 10 559168. 49 0. 00 3325.80 0. 00 MWD 8325. 00 49. 75 196.81 6071.26 -4671. 76 -1544. 75 5954415. 57 559163. 97 1. 29 3337.10 122. 40 MWD 8350. 00 49. 58 197.17 6087.44 -4689. 98 -1550. 32 5954397. 30 559158. 55 1. 29 3350.34 122. 21 MWD 8375. 00 49. 41 197.53 6103.68 -4708. 13 -1555. 99 5954379. 11 559153. 03 1. 29 3363.46 121. 98 MWD 8400. 00 49. 24 197.89 6119.97 -4726. 19 -1561. 76 5954361. 01 559147. 41 1. 29 3376.47 121. 74 MWD 8415. 00 49. 15 197.84 6129.78 -4737. 00 -1565. 24 5954350. 18 559144. 01 0. 68 3384.23 203. 35 MWD 8425. 00 50. 05 197.84 6136.26 -4744. 25 -1567. 57 5954342. 91 559141. 74 9. 00 3389.44 0. 00 MWD 8430. 00 50. 50 197.84 6139.45 -4747. 91 -1568. 75 5954339. 24 559140. 59 9. 00 3392.07 360. 00 MWD 8432. 46 51. 61 197.84 6141.00 -4749. 73 -1569. 34 5954337. 41 559140. 02 45. 00 3393.38 360. 00 1 D-42L1 8450. 00 59. 50 197.84 6150.91 -4763. 49 -1573. 77 5954323. 62 559135. 70 45. 00 3403.26 0. 00 MWD 8475. 00 70. 75 197.84 6161.41 -4785. 04 -1580. 70 5954302. 01 559128. 94 45. 00 3418.75 0. 00 MWD 8500. 00 82. 00 197.84 6167.29 -4808. 13 -1588. 13 5954278. 86 559121. 70 45. 00 3435.34 360. 00 MWD 8517. 78 90. 00 197.84 6168.53 -4825 .00 -1593. 56 5954261. 95 559116. 40 45. 00 3447.47 0. 00 MWD 8525. 00 91. 19 194.82 6168.45 -4831. 93 -1595. 59 5954255. 01 559114. 43 45. 00 3452.54 291. 50 MWD 8550. 00 95. 27 184.31 6167.04 -4856 .50 -1599. 74 5954230. 41 559110. 48 45. 00 3472.03 291. 47 MWD 8562. 78 97. 29 178.90 6165.65 -4869. 19 -1600. 09 5954217. 71 559110. 23 45. 00 3482.95 290. 88 MWD 8575. 00 97. 20 177.05 6164.10 -4881 .31 -1599. 66 5954205. 60 559110. 76 15. 00. 3493.76 267. 50 MWD 8600. 00 97. 01 173.28 6161.01 -4906 .03 -1597. 57 5954180. 91 559113. 05 15. 00 3516.39 267. 27 MWD 8625. 00 96. 79 169.50 6158.01 -4930 .56 -1593. 86 5954156. 41 559116. 96 15. 00 3539.65 266. 80 MWD 8650. 00 96. 53 165.74 6155.11 -4954 .81 -1588. 54 5954132. 20 559122. 48 15. 00 3563.44 266. 35 MWD 8675. 00 96. 25 161.97 6152.32 -4978 .67 -1581. 63 5954108. 40 559129. 58 15. 00 3587.65 265. 91 MWD 8700. 00 95. 94 158.22 6149.67 -5002 .04 -1573. 17 5954085. 10 559138. 23 15. 00 3612.20 265. 49 MWD 8725. 00 95. 61 154.46 6147.15 -5024 .82 -1563. 19 5954062. 41 559148 .39 15. 00 3636.96 265. 09 MWD 8750. 00 95. 25 150.71 6144.78 -5046 .91 -1551. 73 5954040. 42 559160. 02 15. 00 3661.83 264. 71 MWD 8775. 00 94. 87 146.97 6142.57 -5068 .21 -1538. 85 5954019. 22 559173 .08 15. 00 3686.71 264. 36 MWD 8800. 00 94. 47 143.23 6140.54 -5088 .64 -1524. 59 5953998. 90 559187. 49 15. 00 3711.49 264. 03 MWD 8825. 00 94 .05 139.49 6138.68 -5108 .11 -1509. 03 5953979. 56 559203 .22 15. 00 3736.06 263. 72 MWD 8850. 00 93 .62 135.76 6137.00 -5126 .53 -1492. 22 5953961. 28 559220 .17 15. 00 3760.33 263. 45 MWD 8875. 00 93. 17 132.03 6135.53 -5143 .83 -1474. 23 5953944. 13 559238 .29 15. 00 3784.17 263. 20 MWD 8900 .00 92 .70 128.30 6134.25 -5159 .93 -1455. 16 5953928. 18 559257 .49 15. 00 3807.50 262. 97 MWD 8925 .00 92 .22 124.58 6133.17 -5174 .77 -1435. 07 5953913. 51 559277 .70 15. 00 3830.22 262. 78 MWD 8950 .00 91 .74 120.86 6132.31 -5188 .27 -1414. 05 5953900. 18 559298 .83 15. 00 3852.22 262. 62 MWD 8975. 00 91 .25 117.14 6131.65 -5200 .38 -1392. 20 5953888. 25 559320 .78 15. 00 3873.41 262. 50 MWD 9000 .00 90 .75 113.42 6131.22 -5211 .05 -1369. 60 5953877. 76 559343 .46 15. 00 3893.70 262. 40 MWD 9025 .00 90 .25 109.70 6131.00 -5220 .24 -1346. 35 5953868. 76 559366 .77 15. 00 3913.00 262. 33 MWD 9037 .78 89 .99 107.81 6130.98 -5224 .35 -1334. 25 5953864. 75 559378 .90 15. 00 3922.46 262. 30 MWD 9050 .00 89 .89 105.97 6130.99 -5227 .90 -1322. 56 5953861. 30 559390 .63 15 .00 3931.23 267. 00 MWD 9075 .00 89 .70 102.23 6131.08 -5233 .99 -1298. 32 5953855. 40 559414 .91 15. 00 3948.31 267. 00 MWD 9100 .00 89 .50 98.48 6131.25 -5238 .48 -1273. 73 5953851. 11 559439 .53 15. 00 3964.16 267. 02 MWD 9125 .00 89 .31 94.74 6131.51 -5241 .36 -1248. 90 5953848. 43 559464 .38 15. 00 3978.72 267. 04 MWD 9150 .00 89 .12 90.99 6131.86 -5242 .61 -1223. 94 5953847. 38 559489 .35 15 .00 3991.91 267. 08 MWD 9175 .00 88 .94 87.25 6132.28 -5242 .23 -1198. 95 5953847. 97 559514 .33 15 .00 4003.69 267. 13 MWD 9187 .78 88 .84 85.33 6132.53 -5241 .40 -1186. 20 5953848. 90 559527 .07 15. 00 4009.15 267. 20 MWD 9200 .00 88 .84 87.17 6132.77 -5240 .60 -1174. 01 5953849. 79 559539 .26 15 .00 4014.36 90. 00 MWD 9225 .00 88 .85 90.92 6133.28 -5240 .18 -1149. 02 5953850. 41 559564 .24 15 .00 4026.11 89. 96 MWD 9250 .00 88 .86 94.67 6133.78 -5241 .40 -1124. 06 5953849. 40 559589 .21 15 .00 4039.28 89. 89 MWD 9275 .00 88 .87 98.42 6134.28 -5244 .25 -1099. 23 5953846. 75 559614 .05 15. 00 4053.80 89. 81 MWD 9300 .00 88 .89 102.17 6134.76 -5248 .71 -1074. 64 5953842. 48 559638 .68 15 .00 4069.63 89 .74 MWD 9325 .00 88 .92 105.92 6135.24 -5254 .78 -1050. 40 5953836. 62 559662 .97 15 .00 4086.69 89. 66 MWD 9350 .00 88 .94 109.67 6135.71 -5262 .42 -1026. 60 5953829. 17 559686 .82 15 .00 4104.91 89 .59 MWD 9375 .00 88 .98 113.42 6136.16 -5271 .59 -1003. 36 5953820. 18 559710 .14 15 .00 4124.20 89. 52 MWD 9400 .00 89 .02 117.17 6136.60 -5282 .27 -980. 76 5953809. 69 559732 .81 15 .00 4144.50 89 .45 MWD 9425 .00 89 .06 120.92 6137.02 -5294 .41 -958. 92 5953797. 73 559754 .76 15 .00 4165.70 89 .39 MWD Conac Phillips Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~~ ~.~ roc Company: ConocoPhillips Alaska, Inc Date: 4/12/2005 Time: 09:34:50 Page: 4 Field: Kuparuk River Unit Co-ordiuate(NE) Re ference: Well: 42, Tr ue No rth Site: Pad 1 D Vertical (T'VD) Refe rence: Wellhead(106') 106.0 Well: 42 Sectioa(~?SjReference: Well (O.OON ,O.OOE,151 .OOAzi) Wellpath: Pla n#5, 1 D -42L1 Surve y Calcula tion Method: M inimum C urvatu re Db : O racle Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft H ft degl100ft ft deg 9450. 00 89.10 124.67 6137.42 -5307. 95 -937. 91 5953784. 36 559775 .87 15.00 4187. 73 89. 33 MWD 9475. 00 89.15 128.42 6137.80 -5322. 83 -917. 83 5953769. 65 559796 .07 15.00 4210. 48 89. 27 MWD 9487. 78 89.18 130.34 6137.99 -5330. 93 -907. 95 5953761. 62 559806 .01 15.00 4222. 35 89. 21 MWD 9500. 00 89.18 128.51 6138.16 -5338. 69 -898. 51 5953753. 94 559815 .51 15.00 4233. 72 270. 00 MWD 9525. 00 89.19 124.75 6138.52 -5353. 61 -878. 46 5953739. 19 559835. 68 15.00 4256. 48 270. 03 MWD 9550. 00 89.19 121.00 6138.87 -5367. 17 -857. 47 5953725. 79 559856 .78 15.00 4278. 53 270. 08 MWD 9575. 00 89.20 117.25 6139.22 -5379. 34 -835. 64 5953713. 80 559878 .71 15.00 4299. 75 270. 13 MWD 9600. 00 89.22 113.50 6139.57 -5390. 05 -813. 05 5953703. 28 559901 .37 15.00 4320. 07 270. 19 MWD 9625. 00 89.23 109.75 6139.90 -5399. 26 -789. 82 5953694. 25 559924 .68 15.00 4339. 39 270. 24 MWD 9650. 00 89.25 106.00 6140.23 -5406. 94 -766. 03 5953686. 77 559948 .52 15.00 4357. 63 270. 29 MWD 9675. 00 89.28 102.25 6140.56 -5413. 04 -741. 80 5953680. 87 559972 .81 15.00 4374. 72 270. 34 MWD 9687. 78 89.29 100.34 6140.72 -5415. 54 -729. 27 5953678. 47 559985 .35 15.00 4382. 98 270. 39 MWD 9700. 00 89.21 98.50 6140.87 -5417. 54 -717. 21 5953676. 56 559997 .42 15.00 4390. 58 267. 50 MWD 9725. 00 89.05 94.76 6141.25 -5420. 43 -692. 39 5953673. 88 560022 .27 15.00 4405. 14 267. 52 MWD 9750 .00 88.89 91.01 6141.70 -5421. 68 -667. 43 5953672. 82 560047 .24 15.00 4418. 34 267. 58 MWD 9775 .00 88.74 87.26 6142.22 -5421. 31 -642. 44 5953673. 40 560072 .22 15.00 4430. 12 267. 65 MWD 9787. 78 88.67 85.35 6142.51 -5420. 48 -629. 69 5953674. 33 560084 .96 15.00 4435. 58 267. 73 MWD 9800. 00 88.67 87.18 6142.79 -5419. 69 -617. 50 5953675. 22 560097 .14 15.00 4440. 80 90. 00 MWD 9825 .00 88.67 90.93 6143.37 -5419. 28 -592. 51 5953675. 84 560122 .12 15.00 4452. 55 89. 96 MWD 9850 .00 88.69 94.68 6143.95 -5420. 50 -567. 56 5953674. 81 560147 .09 15.00 4465. 72 89. 87 MWD 9875 .00 88.70 98.43 6144.52 -5423. 35 -542. 73 5953672. 16 560171 .93 15.00 4480. 25 89. 78 MWD 9900 .00 88.73 102.18 6145.08 -5427. 83 -518. 14 5953667. 89 560196 .55 15.00 4496. 08 89. 70 MWD 9925 .00 88.75 105.94 6145.63 -5433. 90 -493. 90 5953662. 01 560220 .84 15.00 4513. 14 89 .61 MWD 9950 .00 88.79 109.69 6146.16 -5441. 54 -470. 11 5953654. 56 560244 .69 15.00 4531. 36 89 .53 MWD 9975 .00 88.83 113.44 6146.69 -5450. 72 -446. 87 5953645. 57 560268 .00 15.00 4550. 66 89. 45 MWD 10000 .00 88.87 117.19 6147.19 -5461. 41 -424. 28 5953635. 07 560290 .68 15.00 4570. 96 89. 37 MWD 10025 .00 88.92 120.94 6147.67 -5473. 55 -402. 43 5953623. 11 560312 .61 15.00 4592. 17 89. 30 MWD 10037 .78 88.94 122.85 6147.91 -5480. 30 -391. 59 5953616. 44 560323 .51 15.00 4603. 33 89 .22 MWD 10050 .00 88.14 124.50 6148.22 -5487. 07 -381. 42 5953609. 75 560333 .73 15.00 4614. 19 116 .00 MWD 10075 .00 86.50 127.88 6149.39 -5501. 82 -361. 27 5953595. 17 560354 .00 15.00 4636. 85 115 .96 MWD 10087 .78 85.67 129.61 6150.26 -5509. 79 -351. 33 5953587. 28 560364 .01 15.00 4648. 65 115 .80 MWD 10100 .00 85.61 127.77 6151.19 -5517. 41 -341. 82 5953579. 74 560373 .58 15.00 4659. 92 268 .00 MWD 10125 .00 85.50 124.01 6153.13 -5532. 02 -321. 63 5953565. 29 560393 .88 15.00 4682. 49 268 .14 MWD 10150 .00 85.40 120.25 6155.11 -5545. 28 -300. 53 5953552. 21 560415 .09 15.00 4704. 31 268 .43 MWD 10175 .00 85.33 116.49 6157.13 -5557. 11 -278. 61 5953540. 55 560437 .10 15.00 4725. 29 268 .73 MWD 10200 .00 85.28 112.73 6159.18 -5567. 49 -255. 96 5953530. 36 560459 .83 15.00 4745. 34 269 .03 MWD 10225 .00 85.24 108.97 6161.25 -5576. 35 -232 .68 5953521. 68 560483 .18 15.00 4764 .38 269 .34 MWD 10250 .00 85.23 105.20 6163.32 -5583. 67 -208. 87 5953514. 56 560507 .04 15.00 4782 .33 269 .65 MWD 10275 .00 85.24 101.44 6165.40 -5589. 41 -184. 63 5953509. 02 560531 .33 15.00 4799. 10 269 .97 MWD 10300 .00 85.27 97.68 6167.47 -5593. 55 -160. 07 5953505. 08 560555 .92 15.00 4814 .63 270 .28 MWD 10325 .00 85.32 93.92 6169.52 -5596. 06 -135. 28 5953502. 76 560580 .72 15.00 4828 .84 270 .59 MWD 10350 .00 85.39 90.15 6171.55 -5596. 95 -110 .39 5953502. 08 560605 .62 15.00 4841 .68 270 .90 MWD 10362 .78 85.43 88.23 6172.57 -5596. 77 -97 .65 5953502. 36 560618 .35 15.00 4847 .70 271 .20 MWD 10375 .00 85.37 90.07 6173.55 -5596. 59 -85 .47 5953502. 64 560630 .53 15.00 4853 .45 92 .00 MWD 10400 .00 85.26 93.83 6175.60 -5597. 44 -60. 57 5953501. 99 560655 .43 15.00 4866 .26 91 .85 MWD 10425 .00 85.16 97.59 6177.69 -5599. 91 -35 .79 5953499. 72 560680 .23 15.00 4880 .44 91 .54 MWD 10450 .00 85.09 101.36 6179.81 -5604. 01 -11 .22 5953495. 82 560704 .83 15.00 4895 .94 91 .23 MWD 10462 .78 85.07 103.28 6180.91 -5606. 73 1 .21 5953493. 20 560717 .29 15.00 4904 .34 90 .91 MWD 10475 .00 85.17 105.12 6181.95 -5609. 72 13. 02 5953490. 31 560729 .11 15.00 4912 .68 87 .00 MWD 10500 .00 85.38 108.87 6184.01 -5617. 00 36 .84 5953483 .22 560752 .99 15.00 4930 .60 86 .84 MWD 10525 .00 85.62 112.63 6185.97 -5625. 82 60 .14 5953474 .58 560776 .36 15.00 4949 .62 86 .53 MWD 10550 .00 85.87 116.38 6187.82 -5636. 16 82 .83 5953464. 43 560799 .13 15.00 4969 .65 86 .24 MWD Conoco~illips • • Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ~ ~~ ~~~c Company : Co nocoPhill ips Alaska, Inc Date: 4/12/2005 T ime: 09:34:50 Page: 5 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 42, True North Site: Well: Pad 1 D 42 Vertical (TVD) Reference: Section(VS}.Reference: Wellhead(106') 106.0 Well (O.OON,O.OOE,151 .OOAzi) R'ellpath: Pla n#5, 1 D- 42L1 Surve y Calcula tion Method: M inimum C urvature Db : O racle Sun~ey b1D lncl Azim SS TVD N/S E!W MapN MapE DLS VS TFO Too ft deg deg ft ft ft ft ft deg/100ft ft deg l 10575. 00 86.15 120.13 6189.56 -5647 .97 104.79 5953452. 81 560821 .18 15.00 4990.63 85. 96 MWD 10600. 00 86.44 123.87 6191.18 -5661 .18 125.94 5953439. 76 560842 .44 15.00 5012.44 85. 70 MWD 10625. 00 86.74 127.62 6192.67 -5675 .76 146.19 5953425. 35 560862 .80 15.00 5035.01 85. 46 MWD 10650. 00 87.06 131.36 6194.02 -5691 .63 165.46 5953409. 63 560882 .19 15.00 5058.23 85. 23 MWD 10662. 78 87.23 133.27 6194.66 -5700 .22 174.89 5953401. 12 560891 .70 15.00 5070.32 85. 03 MWD 10675. 00 87.23 131.44 6195.25 -5708 .45 183.91 5953392. 97 560900 .78 15.00 5081.88 270. 00 MWD 10700. 00 87.24 127.68 6196.46 -5724 .35 203.16 5953377. 23 560920 .16 15.00 5105.12 270. 09 MWD 10725. 00 87.26 123.93 6197.66 -5738 .96 223.41 5953362. 79 560940 .52 15.00 5127.71 270. 27 MWD 10750. 00 87.30 120.17 6198.85 -5752 .20 244.57 5953349. 71 560961 .79 15.00 5149.56 270. 45 MWD 10775. 00 87.34 116.42 6200.01 -5764 .04 266.56 5953338. 05 560983 .86 15.00 5170.57 270. 63 MWD 10800. 00 87.40 112.67 6201.16 -5774 .41 289.27 5953327. 86 561006 .66 15.00 5190.66 270. 80 MWD 10825. 00 87.47 108.91 6202.28 -5783 .28 312.61 5953319. 19 561030 .07 15.00 5209.73 270. 98 MWD 10850. 00 87.55 105.16 6203.36 -5790 .59 336.49 5953312. 07 561054 .00 15.00 5227.70 271. 14 MWD 10875. 00 87.64 101.41 6204.41 -5796 .33 360.80 5953306. 53 561078 .35 15.00 5244.50 271. 31 MWD 10900. 00 87.74 97.66 6205.42 -5800 .47 385.43 5953302. 59 561103 .01 15.00 5260.06 271. 46 MWD 10925. 00 87.85 93.91 6206.38 -5802 .98 410.28 5953300. 27 561127 .88 15.00 5274.31 271. 62 MWD 10950 .00 87.97 90.16 6207.29 -5803 .87 435.24 5953299. 59 561152 .85 15.00 5287.19 271. 76 MWD 10962. 78 88.04 88.24 6207.73 -5803 .69 448.01 5953299. 87 561165 .61 15.00 5293.22 271. 90 MWD 10975. 00 88.04 90.07 6208.15 -5803 .51 460.22 5953300. 15 561177 .82 15.00 5298.98 90. 08 MWD 11000 .00 88.04 93.83 6209.01 ~-5804 .36 485.19 5953299. 50 561202 .79 15.00 5311.83 90. 02 MWD LEGEND T Plan-. Plan #5 (42/Plan#5, 1D-42L1) PmnaS 1D<zu Azimuths to True North BP Amoco ~~~~ M Magnetic North: 24.39° Creates By BillMlcnaelson Dace anznoo5 Plan a5 BAKER Magnetic Field c„llta~t Illmllnar ,,~«..,„,.,.,~. HUGHES by Strength 57597nT IodamesOhlinger W.n.•, ,o.:u Dip Angle: 80.76° Direct-(9o7>z67-selo / ~ Date: 4/11/2005 ceu: (soil zso-7375 E-mail. ames.ohlin el rote com ....nii °r«~"MO :°aa-i'.•a i ~`l Model: bggm2004 i 9 C~' a IUO: AM. O•tune WN0°N110•'1 10!.0011 v.a.~ey~ ony. onaw s1.rn~p .„.: .w.w r..~n -4600.. - TIP - . I , . I t REFERENCE INFORMATION -4700 - ~' KOP I- `"' t ~ 'i"S L'--'-i~ -" - 1 L ~'~"`~{ 1 :{ l ~ ~ j~ Co-ordnate (N/E) Reference Well Centre'. 42 True North l 1 -~ ~ t r t 1 .1 + Vertical (TVDI Reference S slam Mean Sea Level End of 9'/100' DLS , , ~~ 1 SeMion (V51 Reference Slal (O OON O.OOEI -4800 'y' 1'~ '. I I:r 11 -'.iC IT`l 1T~"-- MeasuredDepthReference Wellhead(106I 10600 ~ 4 : u ~} 1 ti{~I 11 :I 14 ~{ Calculat on Method M n valor 1D-42L1 Tar eUl1 { - -{ 5 ~ III I {I Ili -{ 1 I -4900_ 1 , 1 < ~'T~ 7 - .7 ... w ~.. .... •.. ,.-. vu....w I l l l t I I I .I I I I I i -r 11I ''Tl IA- i~ ~ 1~.~- -5000. '. {T-r+-til-+, +-- + ',+ _i- it ,~~ r ~,r 1 iL I~ +f 1 .r ~f ,! I 1„1.1 ._L ~ _iL ~r-i~ ~ .+~ 1 ~ _ ~ 5 00 it ( ~ r I _L,ri 1 ! I Ill . + } I III. I ~_-'-`- ~ 1 i '1 I t1r t~_ w -5200- 6 z ill 1;:+I 1 1 -IL Irt 1~ 1i °aa°,., °a• .. ~ , e,A s Q ~ {~ r I is ~ I 1 ~ . I i {jf}j t I - ti 1 ~+I 7+ ~~ r.7 r~~ ... .• ...-.... r -5300 .I 6 r ~ f ~7 rt I ~ C , 1 I +~ ~' i 1 i~ 1 11{ 1 y LI ~.. Ill { ~F 1~ 1 I+ w•,,Ia wa + -544~...~ 9 10 ' ll r 1 - -5500- 12 ,nm „ew.•1 r• ~ -5600--1 I {~-• • 2L1 Tar etll2 13 ^ ] - f I ~ 14 ~I 4900_.] _ .... ++ $700-.]J ". ~ ~ - :. 15 5000- t- } 1 •- _ :.. O -5800-- I - Y (r -~ 1 tt .i'ft + t ~; I$-~ - i t ~I-. ~ y 1 ~r i 31 ~ ~ ' I Planar. lD<zL1 I } 1 sloo r- t -F+~. -ssoo- ,--+ ~j i~- 1 1, i ! r F j i I I ~I 1+~'rtt r .. fI I ~ 1~ -6000 "::i _'_'1 +~1}j1 '}1 I + .1 jI t tD-azLt Tar apes 5200' t l l .::t~ ~;~(}„ i ^-'I I f -(t 1 ~+_1 ~l I r i r 1 ^ ~ fI' ll~; -slao-i `~ ~.t _~ i ,a a ,.t ~ 1 4 ~ r } t I 5300 i -+ ~ -} i I ~i l 1, I ~ -. t i j !.. j + ~ f w f I I~{ -6200- -~~ : ~ I ~'-± ~, t~ «~T~ OC 5400 ~ ~ *` I 'i 1I ~ I ++ I ,,I n ,1 1j _ I } rrLl 1'7~-' r 1 ~ h1- )' t -6300_- _. . _ .. .. •5500- - _ t . I 00-1500-1400-13001200-1100-1000- ~_~-~_ ~~-- ~~~- ~-~'" -_._~.__.____._. ..._._,..- __-___ -: 1.:. ~ 1700 16 _ ! x5600- ~ -'I-, j i- ~- ~! - -900 800 -700 600 500 400 300 200 100 0 100 200 300 400 500 600 700 800 900 d West(-)/East(+) [100ft/in] ~ 5700- *., r. - I 5800- --r L 1-.' '. ~ 1 T 5900 6000-- , L l f - i , i tl _Y, ' .- r: 1i TIP ~~~ L _ ~ ~ 1 iD<2L7 Tar eHl2 ! I 4 { i A f i+ t.. - _- ' ~ ' ': 1 r 6101) ~ a _ KOP -.- ..: 6 - ~ 6 9 10 11 ~ . 1 ~ Entl of 9°/100' DLS 10 14 15 15 I t }.Y L ~- : ' ~ ' 1D-d2L1 Tar eta! 12 6200 ' ' I r i .. 9 5 - .. 1D-42L1 Tar atll3 + }+--~ .t + . ..~~! Plan#5. 1D<2L1 .I .. { j ~~-~ 6300-.. ~ ~.-. I •-i ., I + ;. I sago ... ''1 . 1 i I C 1 l 1 I 1 ! C i I ~ I. I' 1 1 1 T I 7 i ~ ~I i I 7 i i ~-TT''~rl: :I TrTT-T- 2600 2700 2800 2900 3000 3100 3200 3300 34001 3500r 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4 Or 5000 5100 5200 5300 5400 5 0T 5600 5700 58 0 00 6000 6100 6200 6300 6400 Vertical Section at 151.00° [100ft/in] AM • • • • Kuparuk DOBCTD BOP configurat~ 2" CT KB Well 1 D-42 Rig Floor _- Lubricator I SSV Master Valve Base Flan e Page 1 - ~ 1 D-1 20 ~ ~--. s.~~ ~ _ ~• KRU 1 D-42L1 --^ ~ _"~~ • 7. ~ ~ --- _ Proposed 1-Oil 1D-123 tD-124 ,,'~~}~ 10-135 _- ~~' ,•;\y~ ~~ -;, Kuparuk "C" Sand ~~~ tD-OS D~~/ ~ D _~ _ 2050780 1 25 10 39 r - - -.- - --- 1E-33PB1 ~' ~ - Confidential wells are red Y ~ Bt 1Q-1 9 ~ rfD-12s 1E- 10-136 SFD 5/1912005 1D-tze 10-1 2s S~0 ~~ t 0 1 33 `\~~ _ 1 D 128 ~ ~~ .. ~ . 6~t7 1 -137 10-13 10 138 1D-131 tD-1z7 7~0 tD-13a to-t u 1D-127 iD-07 10-OB 1D-141L1 ~ ~~~` 817 \ _ ~Q-37Lz tE-tO5P81 Od O 26 -- ~ ~^J~p tD-37L1 tG-30 1D-30L1 1 a t `~. ~~=18~ ( ~o=a2t_~ T11 N, fc~~,OE, UIVI i 1J 9 -- i ~ 1D-404 N Feet 1o-ao 0 1,000 2p00 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETT/ER WELL NAME ~~~ ~~ ``~ ~ ~- PTD# ~~ ~ - ~ ~~ CHECK WHAT ADD-ONS "CLUE" APPLIES OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well /~'~- /D-° ~~- / Permit No, Z~[r/W `/API No. SD~-vZ~'-~Z`~7 / (If API number Production should continue to be reported as W last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. .l~C; Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RVOIL - 490100 Welf Name: KUPARUK RIV UNIT 1D-42L1 Program DEV Well bore see ~ PTD#:2050780 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permitfee attached- - - - - - - - - - - - - - - - - _ - _ _ - - - - _ - - - - MA- - - - -RETURN CHECK TO OPERATOR:- Multilateral-well bore~fee waived-per 20 AAC 25,005(e} - _ - - - _ - - . - - _ 2 Lease number appropriate------------------_-_---__--._ _-__--___Yes_ .-__-Multilateratwe//segment:-topproduckive interval and TD inAQL025661.--_-----._--_---___--,--_ 3 Unique well-name and number--- -- ---------------------- ----- -- Yes- ---------------------------•------------- - --------- -------------------- 4 Well located in-a-de_fined_pool-_-----------------------_-- -_----_--Yes_ -___-Kupa[ukRiver OilPool,gov_ernedbyC9nservatianOrder-No.4320-_---__--_-_-_---___----_-_ 5 Well located proper distance from drilling unitboundary- - - - - _ - - _ - - - -Yes - - - _ -Conservation 0[der No. 4320 contains n9 spacing restrictions with respecttc drilling unit koundaries. _ - - - - _ 6 Well located proper distance-from other wells- - - - - - - - - - - - - - - - - - - - - - - Yes - _ _ _ - - Conservation Order No. 4320 has no interwell-spacing_rest[ictions, - - _ _ _ - - _ - . - - - - - - - 7 Sufficientacreage available in-drilling unit- - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - _ -Conservation Order Nc. 432C has no interwell_spacingrestricti4ns, Wellbo[e will be_more than 500' from - - - _ _ 8 If deviate[), is_wellbore plat included _ - - _ _ - - _ - . - _ - - _ - _ - - - Yes _ - - _ _ - _ an external property line_whe[e-ownership or_landownershipchonges- - - - - - - - - - - - - - - - - - 9 Operator only affected parley - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - 10 Ope[atofhasappropria#e-bondNfQrce------------------------ --- -----Yes- ---- ------------------------------------------------- ------------------- 11 Permitcanbe[ssuedwithoutconservationorder--_--------------- ---------Yes_ --_-_-___--__--_._-____---____-___-___--__--__---__-__,--___-___---._-- Appr Date 12 Pemliteanbe#ssuedwithoutadminist[ativ_e-appr_oval---------------- --------- Yes__ .-___--__-__--___---__- SFD 5/13/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strataauihorizedbylnjectionOrde[#(putl9#in_camments)_(Fer- NA--- ---------------------------------------------------_--__--___--____-.--_ 15 Allwells_within114-milea[eaofreyiewident[fled(Forservicewellonly)------ ---------NA-__ ,----_------_---_------_-------_----.--------_-__---_- ------------------- 16 Pre-produced injector_dorationofpreAroductionlessthan3months-(FOrseNicewellonly}__ NA_- -_---___--_-__--__--__--__-__---_------------------------------- 17 ACMP-Finding of Consistency-has been issued_forthis project- - - - - - - - - - - - - - - - - - ldA- _ - _ - - - - _ ------------------------------------------------------------------- Engineering 18 Conductorstcing_provided__________________--__--__---_ _.-._---_ NA--_ _---_Ccnductorset_in originalwell,lD-42(200-164}.-____----_--_-__-.__--,_.-___----__.--- 19 Surface-casing-protects allkn4v~nUSDWs--___--___-__-___-_ _.--._--__NA-_ ._---Alt aquifers exempted, 40CFR_147.102-(b}(3).--__--__---_-----------------------__-- 20 CMT_v_ol_adequate-to circulate onconductor&surf-csg--_---_______ _________ NA--_ -_-.Surf_acecasing set in original well._-_--__--___--___--_----___-_-- --__-___---_-_- 21 CMT-voladequa#e-iotie-in long string to surfcsg------------------- --------- NA-- ___-_Pr_oduction-easingsetin original well.-______--__---__-_-__---_----___-__----__--- 22 CMT_willgoyerallknow_n-productivehorizons_-_.--__-_--____ --_--__-No___ -___-Slottedliner_completionplarmed.--__---__--_---__--___-----_- ------------------ 23 Casing designsadeq~ateforG,TB&_permaf[ost------------------ ---------Yes- ----------------------------_-----------.--------_-------------------- 24 Adequate tankage_or reserve pit - - _ - - - - - - - - - - - - - - - - - - - - -Yes - - - Rig is-equipped with steel-pits. -No reservepitplanned, All waste to appropria#e-disposal wells._ - _ _ - - - - , - 25 If a_re~l[ill, has_a 10-403 for abandonment been app-roved - - - - - - - - - - - - - - - - - - NA- - _ , - - - _ - _ - ----------------------------------------------------------------- 26 Adequate wellbore separat]onproposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ - - - _ . Qirectional-plan-provided.- L1-departs from main bore wi#h-no o#her wells p[oximate, - _ - - - - - - _ _ _ - - _ - - _ - 27 If_tliverterrequired,doesitmeetregulations---------------------- ---_---. NA-__ --__-BQPStaCkwillal[eady_be in place,-___-_-_---_---__-_-__---._---_---_-----__---- Appr Date 28 Drilling fluid-pregram schematic_$ equip listadequate- - - - - - - - - - - - - - - - - - - - -Yes _ . - - _ Maximum expected fo[maticn pressure 10,8 EMW. To be_drilled_with 8,8,ppg Fluid and_backpressure via choke an TEM 5!1912005 29 BOPEs, do they meetregulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ . _ - - - friction.- 2 volumes of kill weight mud to-be on location._ Dynamic_overbalance used_previsouly. _ - _ - _ ~(j~ /~ ~ 30 _B_OPE.press rating appropriate; test to_(put prig in comments) - - _ _ - - - - _ Yes _ _ - MASP calculated at X880 psi Planned BOP test 3500 psi. - _ _ - - _ _ - _ - - , - _ - - _ - 1 ~ 31 Choke-manrfold comRlies wlAPt RP-53 (May 84) - - Yes - _ _ - - - _ - 32 Work will occur without operation shutdown---------------------- _--_---Yes-_ _-_-___-___--___---_--__---___--__--__----_-_ -------------------------- 33 is presence-of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ _ _ - _ -1 D-42 ti2S reading 105 ppm.- Mud should p[eclude H2S on-rig, Righas sensors and alarrns.- _ _ _ _ _ - - _ _ _ - - 34 Mechanical condition of wells within AQR verified (For service well only) _ - _ - - _ NA- - ------------------------------------------------------------------------- Geology 35 Permiteanbeissuedwlohydrogen_sulfidemeasures---------------- __--___-No__- -___-1D-42measured 106ppmH2$on-813012004._-----_--__--__--__---__-.___--___---- 36 Data_presented 4n potential overpressure zones - - - - _ - - - - - - - - - - - - - - - -Yes - - _ _ _ - _ Reservoir pressure is expectedto be 9.9 ppg EMW_untiCa fault is crossed, then it may jump_to 10.8ppg, - _ . _ - Appr Date 37 Seismic analysis of shallow gas-zones- - - - - - - - - - - - - - - - - - - - NA_ _ _ - - _ .Well will be drilled using-coiled tubing and dynamically overbalanced pressure drilling techniques to - - - - - SFD 5!1312005 38 Seabed condition survey-(ifoff-shore) - - - - - - - - - - - - - - - - - - - - - . _ - - NA - _ - - maintain a bottom hole circulating pressur@ of 11.2ppg ECD.- - - _ - - _ - --------------------- 39 _Contact namelpttone forweeklyprogress-reports [exploratory only]- - - - - - - - - - - - - - NA- _ - Geologic Engineering Public Commissioner: Date: Date Commissioner: issioner Date ~~~ ~~ ~ ~ ~ ~ S ~~ ~ ~~/~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the. readability of the Well History file and 10 simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • **** REEL HEADER **** MWD 06/10/06 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/07/14 932692 01 2.375" CTK LJ *** LIS COMMENT RECORD *** !!!!!!!!!!! !!!!!!!! Remark F ile Version 1.000 !!!!!!!!!!! !!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION. 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information. STRT.FT 8420.0000: Starting Depth STOP.FT 10918.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-42L1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 17' 56.740"N 149 deg 30' 31.173" W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 14-Jul-05 API API NUMBER: 500292297960 Parameter Information Block #MNEM.UNIT Value Description SECT. 23 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth 051 DIRECTIONAL Other Services Line 1 Remarks • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1D-42 through a milled window in 3 1/2" liner. Top of Window 8414 ft.MD (6129 ft.SSTVD) Bottom of Window 8420 ft.MD (6133 ft.5STVD) (8) The interval from 10894 ft.to 10918 ft.MD (6225 ft.to 6228 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1D-42 at 8294 ft.MD (6051 ft.SSTVD) (10) This well 1D-42L1 was kicked off the plugback wellbore 1D-42L1PB1 at 9750 ft.MD (6137.34 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 69 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1D-42L1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-92L1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP • ---------------------------------------------------- GR GR GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 127 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 4 Total Data Records: 40 Tape File Start Depth = 8407.000000 Tape File End Depth = 10918.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 48 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1D-42L1.xtf LCC 150 CN ConocoPhillips Alaska In WN 1D-42L1 FN Kuparuk River Unit COUN North Slope STAT Alaska • • *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 8 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 127 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 4 Total Data Records: 80 Tape File Start Depth = 8407.000000 Tape File End Depth = 10918.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 88 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/07/14 932692 O1 • r1 LJ **** REEL TRAILER **** MWD 06/10/06 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR 8407.0000 142.7400 8407.5000 134.7300 8500.0000 112.3800 8600.0000 99.8400 8700.0000 88.8600 8800.0000 88.6000 8900.0000 66.6500 9000.0000 81.5500 9100.0000 76.5800 9200.0000 70.0500 9300.0000 69.5300 9400.0000 68.7400 9500.0000 70.8300 9600.0000 84.1600 9700.0000 75.5400 9800.0000 65.0800 9900.0000 61.6900 10000.0000 119.4400 10100.0000 121.2600 10200.0000 125.7100 10300.0000 70.5700 10400.0000 69.7900 10500.0000 71.0900 10600.0000 77.6300 10700.0000 69.7900 10800.0000 72.0050 10900.0000 -999.2500 10918.0000 -999.2500 Tape File Start Depth = 8407.000000 Tape File End Depth = 10918.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX 8407.0000 142.7400 8407.2500 144.2200 8500.0000 112.3800 8600.0000 99.8400 8700.0000 88.8600 8800.0000 88.6000 8900.0000 66.6500 9000.0000 81.5500 9100.0000 76.5800 9200.0000 70.0500 9300.0000 69.5300 9400.0000 68.7400 9500.0000 70.8300 9600.0000 84.1600 9700.0000 75.5400 9800.0000 65.0800 9900.0000 61.6900 10000.0000 119.4400 10100.0000 121.2600 10200.0000 125.7100 10300.0000 70.5700 10400.0000 69.7900 10500.0000 71.0900 10600.0000 77.6300 10700.0000 69.7900 10800.0000 72.0050 10900.0000 -999.2500 10918.0000 -999.2500 Tape File Start Depth = 8407.000000 Tape File End Depth = 10918.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • Tape Subfile 4 is type: LIS **** REEL HEADER **** MWD 06/11/17 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/07/14 932692 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File• ldwg.las • Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 8420.0000: Starting Depth STOP.FT 10918.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-42L1 FLD FIELD: Kuparuk River Unit LOC LOCATION: 70 deg 17' 56.740"N 149 deg 30' 31.173" W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 14-Jul-05 API API NUMBER: 500292297960 Parameter Information Block #MNEM.UNIT Value Description - -- - - -- ---- ------------- - - - - - - SECT. - 23 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks 2 d5 -o~-~ ~ i~as~ • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1D-42 through a milled window in 3 1/2" liner. Top of Window 8414 ft.MD (6129 ft.SSTVD) Bottom of Window 8420 ft.MD (6133 ft.SSTVD} (8} The interval from 10894 ft.to 10918 ft.MD (6225 ft.to 6228 ft.SSTVD) was not logged due to sensor bit offset. (9} Tied to 1D-42 at 8294 ft.MD (6051 ft.SSTVD) (10) This well 1D-42L1 was kicked off the plugback wellbore 1D-42L1PB1 at 9750 ft.MD (6137.34 ft.S5TVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 69 records.. Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1D-42L1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-42L1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP • ____________________________________________________ GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 60 Tape File Start Depth = 8407.000000 Tape File End Depth = 10918.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 69 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MG7D . 0 0 2 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1D-42L1.xtf LCC 150 CN ConocoPhillips Alaska In WN 1D-42L1 FN Kuparuk River Unit • • COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 120 Tape File Start Depth = 8407.000000 Tape File End Depth = 10918.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 129 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/07/14 932692 O1 • • **** REEL TRAILER **** MWD 06{11/17 BHI O1 Tape Subfile: 4 2 records... L.J Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • Tape Subfile 2 is type: LIS DEPTH GR ROP 8407.0000 142.7400 -999.2500 8407.5000 134.7300 -999.2500 8500.0000 112.3800 48.8000 8600.0000 99.8400 27.4000 8700.0000 88.8600 97.8800 8800.0000 88.6000 94.7800 8900.0000 66.6500 61.9300 9000.0000 81.5500 75.3600 9100.0000 76.5800 85.2600 9200.0000 70.0500 67.5500 9300.0000 69.5300 56.2000 9400.0000 68.7400 53.7900 9500.0000 70.8300 36.0100 9600.0000 84.1600 40.1700 9700.0000 75.5400 25.3800 9800.0000 65.0800 53.4600 9900.0000 61.6900 70.0900 10000.0000 119.4400 51.4500 10100.0000 121.2600 15.0400 10200.0000 125.7100 264.2900 10300.0000 70.5700 75.1600 10400.0000 69.7900 83.5200 10500.0000 71.0900 54.2800 10600.0000 77.6300 64.8200 10700.0000 69.7900 155.8100 10800.0000 72.0050 22.9700 10900.0000 -999.2500 6.9600 10918.0000 -999.2500 -999.2500 Tape File Start Depth = 8407.000000 Tape File End Depth = 10918.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet ~~ Tape Subfile 3 is type: LIS DEPTH GRAX ROP 8407.0000 142.7400 -999.2500 8407.2500 144.2200 -999.2500 8500.0000 112.3800 48.8000 8600.0000 99.8400 27.4000 8700.0000 88.8600 97.8800 8800.0000 88.6000 94.7800 8900.0000 66.6500 61.9300 9000.0000 81.5500 75.3600 9100.0000 76.5800 85.2600 9200.0000 70.0500 67.5500 9300.0000 69.5300 56.2000 9400.0000 68.7400 53.7900 9500.0000 70.8300 36.0100 9600.0000 84.1600 40.1700 9700.0000 75.5400 25.3800 9800.0000 65.0800 53.4600 9900.0000 61.6900 70.0900 10000.0000 119.4400 51.4500 10100.0000 121.2600 15.0400 10200.0000 125.7100 264.2900 10300.0000 70.5700 75.1600 10400.0000 69.7900 83.5200 10500.0000 71.0900 54.2800 10600.0000 77.6300 64.8200 10700.0000 69.7900 155.8100 10800.0000 72.0050 22.9700 10900.0000 -999.2500 6.9600 10918.0000 -999.2500 -999.2500 Tape File Start Depth = 8407.000000 Tape File End Depth = 10918.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • • Tape Subfile 4 is type: LIS .y~p,~ ~fi **** REEL HEADER **** MWD 06/11/17 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 05/07/10 932692 01 2.375" CTK *** LIS COMMENT RECORD *** ~~~ ~ ~~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 8407.0000: Starting Depth STOP.FT 10300.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANX: ConocoPhillips Alaska, Inc. WELL. WELL: 1D-42L1PB1 FLD FIELD: Kuparuk River Uni t LOC LOCATION: 70 deg 17' 56.740"N 149 deg 30' 31.173" W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 10-Jul-05 API API NUMBER: 500292297970 Parameter Information Block #MNEM.UNIT Value Description ----------------- -------------- SECT. 23 Section TOWN.N 11N Township RANG. 10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 106 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 106 Elevation of Kelly Bushing EDF .F N/A Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks aos--o~~ ~-<<a~a • • (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure and Downhole Weight on Bit), a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (6) Data presented here is final and has not been depth adjusted to a PDC (Primary Depth Control)log. The INTEQ MG7D Gamma Ray is the PDC for this wellbore. (7) The sidetrack was drilled from 1D-42 through a milled window in 3 1j2" liner. Top of Window 8415 ft.MD (6130 ft.SSTVD) Bottom of Window 8421 ft.MD (6134 ft.SSTVD) (8) The interval from 10276 ft.to 10300 ft.MD (6170 ft.to 6174 ft.SSTVD) was not logged due to sensor bit offset. (9) Tied to 1D-42 at 8294 ft.MD (6051 ft.SSTVD) (10) The well 1D-42L1 was kicked off this plugback wellbore 1D-42L1PB1 at 9750 ft.MD (6137.34 ft.SSTVD) MNEMONICS: GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feetjhour TVD -> Subsea True Vertical Depth, feet Tape Subfile: 1 67 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------------- WDFN 1D-42L1PB1 5.xtf LCC 150 CN ConocoPhillips Alaska Inc. WN 1D-42L1PB1 FN Kuparuk River Unit COUN North Slope STAY Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has not been depth shifted *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 46 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 2 55 Minimum record length: 54 Maximum record length: 4124 **** FILE HEADER **** MWD .002 1024 8407.500000 10300.000000 0.500000 feet records... bytes bytes ~1 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1D-42L1PB1.xtf • • LCC 150 CN ConocoPhillips Alaska In WN 1D-42L1PB1 FN Kuparuk River Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 91 Tape File Start Depth = 8407.250000 Tape File End Depth = 10300.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 100 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 05/07/10 • ~ 932692 01 **** REEL TRAILER **** MWD 06/11/17 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS • • Tape Subfile 2 is type: LIS DEPTH GR ROP 8407.5000 134.7300 -999.2500 8408.0000 110.4000 -999.2500 8500.0000 112.3800 48.8000 8600.0000 99.8400 27.4000 8700.0000 88.8600 97.8800 8800.0000 88.6000 94.7800 8900.0000 66.6500 61.9300 9000.0000 81.5500 75.3600 9100.0000 76.5800 85.2600 9200.0000 70.0500 67.5500 9300.0000 69.5300 56.2000 9400.0000 68.7400 53.7900 9500.0000 70.8300 36.0100 9600.0000 84.1600 40.1700 9700.0000 75.5400 25.3800 9800.0000 .84.6800 31.9100 9900.0000 92.0000 68.9900 10000.0000 85.7300 55.8200 10100.0000 71.0900 79.7000 10200.0000 71.0900 71.6800 10300.0000 -999.2500 -999.2500 Tape File Start Depth = 8407.500000 Tape File End Depth = 10300.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • • Tape Subfile 3 is type: LIS DEPTH GRAX ROP 8407.2500 144.2200 -999.2500 8407.5000 134.7300 -999.2500 8500.0000 112.3800 48.8000 8600.0000 99.8400 27.4000 8700.0000 88.8600 97.8800 8800.0000 88.6000 94.7800 8900.0000 66.6500 61.9300 9000.0000 81.5500 75.3600 9100.0000 76.5800 85.2600 9200.0000 70.0500 67.5500 9300.0000 69.5300 56.2000 9400.0000 68.7400 53.7900 9500.0000 70.8300 36.0100 9600.0000 84.1600 40.1700 9700.0000 75.5400 25.3800 9800.0000 84.6800 31.9100 9900.0000 92.0000 68.9900 10000.0000 85.7300 55.8200 10100.0000 71.0900 79.7000 10200.0000 71.0900 71.6800 10300.0000 -999.2500 -999.2500 Tape File Start Depth = 8407.250000 Tape File End Depth = 10300.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • • Tape 5ubfile 4 is type: LI5